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184-067
Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#12AͲ04 50Ͳ103Ͳ20026Ͳ00 909593518 Kuparuk River Plug Setting Record FieldͲFinal 29ͲSepͲ24 0 122AͲ05 50Ͳ103Ͳ20030Ͳ00 909524907 Kuparuk River Plug Setting Record FieldͲFinal30ͲAugͲ24 0 132AͲ11 50Ͳ103Ͳ20057Ͳ00 909594128 Kuparuk River Multi Finger CaliperField & Processed 4ͲOctͲ24 0 142AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Multi Finger CaliperField & Processed 22ͲAugͲ24 0 152AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Packer Setting Record FieldͲFinal 24ͲAugͲ24 0 162GͲ10 50Ͳ029Ͳ21140Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 23ͲAugͲ24 0 172MͲ07 50Ͳ103Ͳ20178Ͳ00 ALSL765Ͳ008 Kuparuk River Multi Finger CaliperField & Processed 15ͲSepͲ24 0 182NͲ329 50Ͳ103Ͳ20257Ͳ00 909593520 Kuparuk River Packer Setting Record FieldͲFinal 20ͲSepͲ24 0 192ZͲ10 50Ͳ029Ͳ21378Ͳ00 909593519 Kuparuk River Multi Finger CaliperField & Processed 25ͲSepͲ24 0 110 3IͲ09 50Ͳ029Ͳ21561Ͳ00 909619414 Kuparuk River Leak Detect Log FieldͲFinal 5ͲOctͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39689T39690T39691T39692T39692T39693T39694T39695T39696184-053184-067186-003186-004184-106192-080198-067185-137186-055T3969710/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:49:24 -08'00'2AͲ0550Ͳ103Ͳ20030Ͳ00 909524907KuparukRiverPlugSettingRecordFieldͲFinal30ͲAugͲ240184 05384-06786 003T39690 Ima ect Well History File ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original, file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing (done) RESCAN DIGITAL DATA Color items: [] Diskettes, No. Grayscale items: [] Other, No/Type Poor Quality Origi hals: Other: , NOTES: BY: BEVERLY BREN VINCENT SHE~OWELL DATE: Project Proofing BY: BEVERLY BREN~y SHERYL MARIA LOWELl. Scanning Preparation ~ -._ x30 = OVERSIZED (Scannable) [3 Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) ~E] : Logs of various kinds Other Is~ BY: BEVERLY BRF, N~ SHERYL MARIA Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: LOWELL DATE: ~ + ! = /si .~ TOTAL PAGES ~.x~/. NO NO PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BY: ~BRE. V,NCE.T S.ERY' MAR,A LOWEL. DATE:)I.t~0~-- Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY~ BEVERLY BREN VINCENt'MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN IND~/IOUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARia LOWELL DATE: /SI General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 8, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Pressure Build Up: 2A -05 Run Date: 8/10/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20030 -00 6i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto o1 Q f job /e6 t5)-0 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 Fax: 907 -2731 rafael.barreto@halliburton.com NOV 0 5 7009 A,iaska 019 Gas Cons. Cofl issior Date: Anchorage Signed: Page 1 of 1 Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocophillips.com] Sent: Monday, November 17, 2008 8:22 AM To: Maunder, Thomas E (DOA) Subject: RE: 2A-05 (184-067) Attachments: 2A-05 dog leg severity graph.PDF; 2A-05 7 inch Casing Pulled 009.jpg; 2A-05 7 inch Casing Pulled 007.jpg Good morning Tom, Yeah, a real gem. Severe buckling near surface was new for me. I believe the 7" was originally landed in tension but well subsidence, ~5', eliminated that stress and then some. When the csg was cut recently, it acted like the 200M# tension we put on it in July (42" csg removed) wasn't there either. The tight spots are believed to be from buckling. Caliper and gyro data support this assertion as well as being able to drag a 5.9" GLM up through in July but drag seen on 2.875" Hydril 511 going in. Luckily we only have a few more w/ similar buckling problems at 2A, so far. We've got a CFER study going to model & investigate potential mitigation. Banana curved 7" pics & gyro DLS graph attached. The RBP "went south" while cleaning the sand off. They didn't think they were down°to the plug yet and snagged the fishing neck w/ the inside fingers on the shoe. Pulling off allowed the plug to equalize and begin its southern migration. Jim Ennis j j.ennis@conocophillips.com ~. (907)265-1544 (IAA <:_r .~, ~~j_- I~~':°. (907)632-72$1 (C) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, November 16, 2008 12:31 PM To: Ennis, J J Subject: 2A-05 (184-067) Jim, 1 am reviewing the 404 submitted for the latest work on this well. Quite a bit of tight casing!! Is there any speculation on how the tight spots might have developed? I think it is apparent that the casing was landed in compression. Does the informa#ion when the well was drilled provide information on any issues when the 7" was run? Alsa, it appears that the RBP "went south" at some time after the initial pressure test. I'd appreciate any information you might have. I look forward to your reply. Tom Maunder, PE AOGCC 12/24/2008 i _ ~ ;~~ ~ = ~ ~ ~ :~ ~~ ~~ ., 1'. ~ G R~~ F ,~~ .:.. a ,. ~ ~ ~ ~ Y~r ~9 G ~ ,,~ ~_ ~ ~ Q ~ ,~ ~ ~ ,) e ` ~ ~~ ~~ I '~ ~ ~ . ~ ~ a ~' 1~x , ~~ ~ ~ f '~ ~ ~ ~ ~~ ~ ~~ ~~ ~b ~ ~ ~ ~ ~ i •ti ~~-~~ a ~~ ~ ~~ ./ I . ...~ ;~ ^ e J.• ~., ~ `;~ ~ I ,~F~ J' 1~ ~ ~~¢ ~ L ~,' 1~ i ~ • ~ ~ ~ ~. :' t 'yr w f f r ~. ~ t ~ , w ~ ~ ~ f ~ ~ •. ~ w ' lw ~t ~ • ~ w 7 . ~ ; Y~ ~:: _ ~' r. A. ~ + • • / JAI • ., ~ R Y 'Y~~f ~ • . +' ~ w' t•~'t; wt~+•~~~ ~ ~ f ~•~ t.~. ip ~•~ 1.~~ .r.; r C.~l'~•l~lw*f.'~~~. t. ~* '~ ,,t^ .fit t.,,~ ~, ~ k ,y ~ •~P ~~ ~ f~.t M " :,e '~ & ~ 4 _ ~ n I ~ ~ ~ ~ • I ~ } I I p~~ ~~ yy r' r I\ • Dog Leg Severity (deg/25') • 99.2 121 143 166 187 209 231 253 276 297 320 341 363 385 408 429 451 473 495 v 517 539 561 583 605 627 649 671 693 715 738 760 782 803 825 847 869 891 913 N 0 n 0 3 c 0 c N 0 v 0 ca r c~ cc e~ rt O N A O Oo O N Extension request for 2A-OS on 10-25-08 Page 1 of 1 • Maunder, Thomas E (DOA) From: Jones, Jeffery B (DOA) Sent: Saturday, October 25, 2008 8:35 PM To: Nordic 3 Company Man Cc: Crisp, John H (DOA); Jones, Jeffery B (DOA); Noble, Robert C (DOA); Regg, James B (DOA); Scheve, Charles M (DOA); Maunder, Thomas E {DOA) S Subject: RE: Extension request for 2A-05 on 10-25-08 ~ p~ ~.: ~~ G IU ~ J Randy and Rick, After speaking with you, reviewing your current situation and plan forward and discussing your extension request with my supervisor Jim Regg, your request for a BOPS test extension is denied. I understand that you are in the hole at this time with aback-off tool so test BOPE as soon as you are out of the hole. I am waiving AOGCC witness of this BODE test. The assumption in this case that you are working under diverter regulations with a BOPE stack installed on the well is in error, absent a specie variance stating as such, issued from the AOGCC engineering sfiaff. In the future, when requesting an extension of this type please identify the time period of the extension (24, 36, 48 hrs. etc.) in your written request. Thanks for your cooperation, Jeff Jones AOGCC From: Nordic 3 Company Man [mailto:n1433@conocophillips.com] Sent: Saturday, October 25, 2008 6:55 PM To: aogcc._.prudhoe_bay@admin.state.ak.us Subject: Extension request for 2A-05 on 10-25-08 Jeff, Nordic 3 is requesting an extension for weekly BOP test due 10-25-08 for 2A-05. As we will be screwing in a new 7" casing string @ 1,737' in the early AM of 10-26-08. This string will be Cemented in place then BOP's will be Nippled Down to install 7" casing slips on 10-26-08. We will be installing the Tubing head and Nippling up BOP's. This will require a full Test (aZ that time. If any questions feel free to call. Thanks, Randy and Rick Rick Overstreet /Peter Nezaticky (Days) Randy Dolcater / Rance Peterson (Nights) Nordic 3 Co Man Office: 907-659-7446 Fax: 907-659-7566 11/16/2008 Page 1 of 3 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Wednesday, August 27, 2008 8:26 AM To: Maunder, Thomas E (DOA) Subject: RE: 2A-06 (184-067) Tom, As a follow-up to our conversation regarding the two mill/motor assembly trips on 1'° CS Hydril tubing, I discussed it with the rig supervisor and the toolpusher and considering the shallow depth of our tight spot we were drifting (between 106' to 264'), they were under the impression that the 1"tubing was considered part of the motor/mill assembly BHA which would not require the BOP to be configured for that size pipe. What led up to the need for the 1"tubing is as follows: When we initially backed out the lock-down screws on the hanger, it jumped 6". We pulled on the hanger up to 150K while circulating and could not pull the pipe free. When we relaxed on the pipe, it came to rest 3 feet higher. We decided to fire a stringshot across the PBR to see if we could free the pipe, and since we already had slickline stood back, we opted to make some drift runs while waiting on Eline to arrive with the stringshot. They attempted several drifts: 1st: 10' of 2.625" --> set down at 106' 2nd: 10' of 1.875" --> set down at 227' but worked it to 2031' 3rd: 8' of 2.125" --> worked through tight spots from 217' to 264', would not go further Rigged down slickline, pulled 14,000 Ibs on tubing, rigged back up slickline. 4th: 8' of 2.125" --> set down at 228', pulling tension seemed to make it worse 5th: 18' of 1.5" --> bobbled through tight spots from 217' to 264', made it down to 8561' 6th: 10' of 1.875 --> bobbled through tight spots from 217' to 264', ran in to 1000' We rigged up Eline and fired a stringshot and worked the pipe some more up to 150K Ibs, but no luck. We decided it was time to chemical cut the tubing. We wanted to make sure we could get through the tight spot with the chemical cutter, so we decided to make a drift run w/ a mill and motor assembly. We had to use smaller pipe as part of the BHA because we knew from previous drifts with slickline that anything rigid would not pass through the tight spots unless it had a very small diameter. Due to the hanger resting 3' high, we couldn't push the hanger back down so we set the 3.5" landing joint in the slips. At this time with the 3.5" landing joint set in the slips, we had two barriers which were a WRP set at 8591' RKB below the top packer, and 9.6 ppg brine in the hole which was well above the 8.8 ppg KWF needed. The well had passed a CMIT indicating the upper packer was good and the WRP was holding. The BOP stack was configured with 3.5" rams in both the upper and lower pipe rams, blind rams, and an annular preventer. The intention was to just drift through the tight spot between 106' and 264' with the motor/mill assembly, but they ran to 520' just to be sure we were clear of restrictions below this bad section. They didn't see anything restrictions with the 2.30" mill, so they swapped over to a 2.80" mill (almost afull-bore drift) and it passed through also without restrictions, thus indicating that our tubing was not pinched, just extremely buckled in that section. This gave us confidence that we would be able to run the chemical cutter, because shorter BHA's w/ larger OD's will drift through the tight spots, just not longer rigid BHA's. We ran the 2.125" chemical cutter, it bobbled a little bit from 130' to 260', but made it through and had a successful cut at 8536' MD. We had to jar on the chemical cutter on the way out of the hole to pull it through the tight spot. Once cut, we pulled the tubing and then began the casing inspections and the rest is history and I won't address it here since this is just a response to the use of the 1"tubing. 12/24/2008 Page 2 of 3 C~ As far as this well goes, we had no choice but to use a smaller OD pipe as part of our BHA, and I know this question has come up in the past about what is considered part of the BHA, or what is an acceptable length of the BHA. In this case, if our tight spots began at 106' and extended down to 264' as indicated by the slickline drifts, we would need at least 160' of the 1" pipe as part of the BHA just so the motor/mill could extend through the tight spots. At which point we could have switched over to a 2-3/8" pipe, a size we could configure our BOP stack to accommodate, but with 2-3/8" pipe, we could only run an additional 106' before the 2-3/8" would hang up in the tight spot, so just to be sure we didn't have any additional tight spots below the 264', we needed to run additional 1" pipe, and we ran into 500 feet at which point we were sure we had drifted any tight spots. Due to the shallowness of this restriction that we were drifting, we considered all of this as part of the motor/mill BHA. Had the tight spot been deeper, say 2000' vs. 200', we probably would have ran with the same length of 1" pipe to get through the restriction, but conveyed the 1" in on our 3.5" drillpipe, where in this case we would have considered the 1" to be part of the 8HA also. We couldn't very well configure the BOP's for smaller pipe for a couple reasons: First of all, because we don't have any 1" rams because we never use 1" pipe as tubing, liner, casing or drill pipe; whenever used, it is always in conjunction with a BHA. Secondly, in order to changeout the rams to accommodate any size smaller pipe, it would have required us to land the tubing hanger back in the tubing head and this would have proved difficult since the tubing had released all that trapped energy and came to rest 3' high. Our only option would have been to stack out weight with the top drive on the landing joint to try and push the tubing back downhole 3', which I don't believe we had enough weight to even do that. That would also pose a safety hazard purposefully trapping 35,000 Ibs of stored energy in that tubing. This well gave us many surprises and we handled them the best we could under the circumstances. As a follow-up, after the tubing was pulled, we discovered the 7" casing to be in the same condition as the tubing, severely buckled, this was obvious when we had trouble trying to run the completion, and in the end, when we ran the 2-718" Hydril 511 kill string, we even had to push that pipe through the shallow tight spot in the 7" casing. Following the workover, we have run a gyro and discovered 6°/25ft doglegs in that section. The well is back on the workover list and plans are to cut and pull the bad 7" and re-land new 7" and cement to surface. Please let me know if you have any further questions you would like addressed. ,~ Brett Wacker ~Dri~ng s~'WeQs zNorkover Engineer 4Nork# 265-6845 Cetl'# 230-8377 Prom: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 06, 2008 3:31 PM To: Packer, Brett B Cc: Regg, James B (DOA) Subject: 2A-OS (184-067) Brett, I have reviewed the operations summary submitted with the 404 for the recent rig work conducted between July 10 and July 20 on this well. We have already messaged regarding the need to have contacted the Commission and likely submitted a Sundry Notice (Form 403) when it was determined to halt operations. While the initial work scope did not require a sundry notice, halting the operations without the well being "completed" should have been communicated to us. With regard to the operations summary, I note on July 15 that two mill/motor assembly trips on 1" CS Hydril tubing were run into the 3-1/2" tubing to 520'. What was the BOP ram configuration when these runs were made? Was the stack properly equipped to meet the requirements of 20 AAC 25.285 (c) (2) (A)? Please note the Commission reserves the right to pursue an enforcement action in this matter if it is determined that the stack was not properly equipped as required. Call or message with any questions. 12/24/2008 STATE OF ALASKA ~ ~ ~ ~~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION £h „ REPORT OF SUNDRY WELL OPERATIONS' ` `' - 1. Operations Performed: Abandon ^ Repair Well ~ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing Q Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Welt Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 184-067 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20030-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 130' 2A-05 ' 8. Property Designation: 10. Field/Pool(s): ADL 25570 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9185' ' feet true vertical 6236' feet Plugs (measured) Effective Depth measured 3485' feet Junk (measured) 8907' true vertical 2786' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 104' 16" 104' 104' SURFACE 3209' 9-5/8" 3209' 2619' PRODUCTION 9060' 7" 9060' 6152' Perforation depth: Measured depth: 8692'-8730', 8762'-8784', 8796'-8855' true vertical depth: 5904'-5930', 5951'-5966', 5974'-6013' Tubing (size, grade, and measured depth) 4.5" / 3.5", L-80 / J-55, 8515' / 8791' MD. Packers & SSSV (type & measured depth) pkr- BAKER'FHL' ; BAKER'FB-1' pkr= 8494', 8568' ; 8781' Camco'DB' nipple C~ 488' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 200'-400' 16 bbls AS1 squeezed into 9-5/8" casing leaks @ 200'-400' Treatment descriptions including volumes used and final pressure: with 40 psi sqz pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI ~ -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-314 Contact im Ennis @ 265- 1544 Printed Name im Ennis Title Wells Group Engineer Signature r Phone: 265-6845 Date ~/ ~~ ~~ Pre red S aron I/s Dr k 263-4612 Form 10 Revised 04/2006 ~y; E"~ ~ ~`i ~ e~ ~ "'"-~ ~'~~~ 3~ t~ `Q~~ Submit Original Only yf("~f ~~y cauoucroR, 0-1% NIPPLE 699 PRODUCTION (nxw), -]-1,]60 GAS LIFT, z.7s2 SURFACE, 0-3.209 GAS LIFT, d7u Casing Description SURFACE (kKB KUP - 2A-05 es Field Name ''Well Status ProNlnj Well Type Inc! (°) MD (HKB) TD (maz) (fi KUPARUK RIVER UNIT PROD ~ I _57.02 7,20000 I 9,1850 H25 (ppm) (Date Annotation IEntl Data KBGrtl (ft) -Rig Release Data 220 7/1/2008 Last WO: '~. 11/2/2008 40.50 ~ 6/28/1984 Dep[h (flK8) IEntl Data , Annotation End Date 8,840.0 ~ 3/4!2004 Rev Reason' Pull RHC Ball/Rod, Pull WRP, GLV C/O 11/9/2008 gs String S ' _ TOp (HKB) Set Depth (f... Set Depth (TV D) ... String W1... String ... String Top Thrtl 6 t S 060 0.0 104.0 104.0 fi2.50 HAO '.String 0... String ID ... Top (ftK6) Set Depth (f... it Set Depth (TVD) ... Siring Wt...'Stdng ... String Top Thrtl 9518 8.765 0.0 3,209.0 2,618.3 36.00 I J-55 String O... String lD ... Top (ftK6) Set Depth (f... Set Depth (TVD)... String Wt... String.. . String Top ThM lew) 7 6.151 -7.2 1,739.7 1,642.3 26.00 L-80 BTCM String 0... String ID ... Top (ftK6) Set Depth (i... Set Depth (ND) ... String Wt... String ~~ ~ String Top Thrtl 7 6.151 1,739.0 9,060.0 6,151.9 26.00 J-65 gs ',String 0... String ID ... Top (ftK6) '' Set Depth (f... Set Depth (TVD) ... i 51 g WI... 1151 'ng ... String Top Thrtl 41/2 3958 ~ 00 8,575.3 ~~ 5,7906 1260 I L80 1 IBT Mal letails pth _ -- Top Inc! (°) Hem Desttiption Comment ID (il 3.6 0 40 HANGER FMC Gen V, SM, 4 1/2 IBT Landing threads w/ 4 1/2 Pup jt 3.9( 7.6 0.41 NIPPLE 3.875" ID DB XN Nipple i 3 8: 3 7 50.79 NIPPLE 3.812" ID DB XN Nipple - 1 3.81 9.6 50.72 XO -Reducing 4 1/2" IBTM Box z 3 1l2 EUE 8rd Pin Crossover Sub 3.9`, 5.8 50.45 SEAL ASSY Baker 80-00 Seal assy wl locator (space out 2.34') 3.0( 7.4 50.43 PBR Baker"PBR" ~ 3.0( 6.0 50.34 PACKER Baker "FHL" 4762 - 7" 26d Packer ~ 2 9~ 3.4 51.06 NIPPLE 3.6" x 2.812" Camco'DS' Nipple 1 2.81 6.6 50.98 OVERSHOT Baker Poorboy Tubing S[ub Overshot 13.61 8RD EUE ABM GAS LIFT. 6.158 GAS LIFT. 7.613 GAS LIFT. 8.382 NIPPLE.86'2] SEAL ASSY, a.d7s PBR. 6.681 PACKER. 8.0% NIPPLE. B.SW OVERSHOT. 8,509 PBR, 8.555 PACKER, 8,568 PRODUCTION, 8.60] PRODUCTION, 8,6]5 APERF. 6.6928.730 RPERF, 6,766-8,776 APERF. 6 ]628.780 PACKE R. 6.761 - -- FISH. 8.50] PRODUCTION -- (original), 1,739-9.060 TD, 9,185 5,893.1 8.907 O Perfora Top (kKB) I 6 048.5 tions B1m (ftK6) 4250'' FISH 1" GLV FELL TO RATHOLE ' Top (rvD) elm (FVD) ! (ftK6) (ftK6) Zone Data _ 16/2/1999 I 0 000 l Shot _ _.. ____. Dens (ah... Type Comment 8,692.0 8,730.0 5,904.4 5,929.8 C-4, UNIT B, 6/28/7984 12.0 APERF 120 deg ph; 5.5" Csg Gun 1 2A-05 8,762.0 8,784.0 5,951.2 5,965.9 A-0, 2A-05 6/28/1984 4.0 APERF 90 deg. ph; 4" Csg Gun 8,764.0 8,776.0 5,952.5 5,960.5 A-4, 2A-05 618/1988 4.0 RPERF Zero deg. phasing; Gearhard EJ II 8,796.0 8,855.0 5,973.9 6,013.4A-3, 2A-06 6/25/1984 4.0 RPERF 90 deg. ph; 4" Csg Gun 8,798.0 ' 8,534.0 S 975.2 5,999.2'A-3, 2A-05 16/8/1988 4.0 RPERF Zero deg. phasing; Gearhard EJ II "~ Notes: General 8 Safety End Date _ Annotation _ _ _ 6/3/1999 NOTE: Well has serious scale problems. 1!22/2004 ,NOTE: CORKSCREWED TUBING STARTING @ 8659' WLM 8/31/2004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 5/1/2008 NOTE: CORKSCREWED TBG FROM 8535' 9/2/2008 NOTE: SCMT 7/19/2008 SHOWS TOP OF CEMENT @ 1970' 111412008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 9andrel Details Top De Pth Top 1-.-_.---_ ___.. Port. (ND) ~ Inc! OD ~ Valve Latch S¢e TF n Top (flK8) (HKB) ~ (°) Maka Motlel (in) Serv Type Type (in) 1' 2,7620! 2,343.3 52.03 Camco KBG-2-1R 1 Gas Lift I ~ GLV BK 0.156 1 2 4,714.5 3,498.6 54.01 Camco _ KBG-2-1R 1 Gas Lift GLV BK 3/16 1 3 6,158.2 4,397.6 49.63 Camco KBG-2-1R 1 Gas Lift 1 OV BK 1/4 __.. __ 4 7,413.4 5,149.7 56.93 Camco __ KBG-2-1R 11 . Gas Lift DMY BK-5 _- 0 5 8,381.7/ 5, 705.1 51.57 Camco KBG-2-1R 1 ~Gas Lift i DMY BK-5 0 2A-05 Well Work Summary DATE SUMMARY 8/13/08 RUN GYRO FROM SURFAC 2500'. TAKE READINGS IN CONTINUOUS MODE FROM 900' TO 2500' AND TAKE STOPS FROM 900' TO SURFACE. 9/13/08 LOG GYRO SURVEY FROM SURFACE TO 2500'. 11/6/08 PULLED BALL & ROD @ 8503' RKB. PULLED SOV @ 6158' RKB & REPLACED WITH DV. MIT IA 2500 PSI, GOOD. PULLED DVs @ 6158', 4715' & 2762' RKB. SET OV @ 6158', GLV @ 4715' RKB. IN PROGRESS. 11/7/08 SET GLV @ 2762' RKB. PULLED RHC PLUG @ 8503' RKB. PT TBG 2000 PSI, GOOD. BAILED FILL OFF CATCHER SUB, PULLED SAME @ 8591' RKB. ATTEMPTED PULL WRP ENCOUNTER FILL. IN PROGRESS. 11/8/08 PULLED 3.5" WRP u, 8591' RKB. COMPLETE. ConocoPhillps Time Log & Summary ~~,h~~, ~e~ R~~~,-~;~9 Report Well Name: 2A-05 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 10/17/2008 10:30:00 AM Rig Release: 11/2/2008 2:30:00 AM Time Logs li - ---- Date From To Dur S. Depth E D~th Phase Code Subcode T Comment _ __ _ 10/16/2008 _ 2a hr Summary Freeze protected 1 D-140, secured well, RDMO, cleaned well site, removed 11" BOP stack for storage, started ri move to 2A ad. 21:00 00:00 3.00 COMPZ MOVE MOB P Move rig from 1 D pad to KOC. 10/17/2008 Moved rig to 2A pad, loaded 13 5/8" stack in cellar, spotted rig over well and bermed up, RU kill tank and hardline, circulated diesel from well, installed test dart, ND tree, NU BOPE. 00:00 06:00 6.00 COMPZ MOVE MOB P Continue move rig from 1D pad to CPF-2 06:00 07:00 1.00 COMPZ MOVE WOCC P Wait on field change out. 07:00 09:30 2.50 COMPZ MOVE MOB P Move rig from CPF-2 to 2A pad. 09:30 11:00 1.50 COMPZ RPCOM RURD P Acce ted Nordic 3 Ri 10:30 hrs 10/17/2008. P/U 13 5/8" stack, put in cellar. 11:00 14:30 3.50 COMPZ RPCOM RURD P Move rig over well 2A-05. Install handy berm containment around cellar. RU hardlines to kill tank. Pull BPV. 14:30 17:00 2.50 COMPZ RPCOM CIRC P PJSM, pressure test lines, circulate 115 bbls hot seawater to displace diesel at 5 bpm - 680 psi taking returns to kill tank, mixed safelube to 110 bbls and pumped at 5 bpm - 580 psi, taking returns to pits, blow down and RD circ liines. 17:00 17:30 0.50 COMPZ RPCOM OTHR P Set BPV. 17:30 00:00 6.50 COMPZ WELCTL NUND P ND tree, installed test dart - NU 13 5/8" BOPE. 10/18/2008 Test BOPE, POOH LD kill string, MU 3.75" multi-string cutter, PU and single in hole to 1,717' Nordic 3 RKB, cut 7" cs . 00:00 01:00 1.00 COMPZ WELCTL OTHR P RU test lines, purge test lines, she-1 test stack, RU chart recorder, grease choke manifold and mud cross for test. 01:00 08:00 7.00 COMPZ WELCTL BOPE P Chart BOP test, low pressure 250 psi -high pressure 3,000 psi, 2,500 psi on annular. AOGCC Rep Lou Gramaldi witnessed all tests. 08:00 09:00 1.00 COMPZ WELCTL OTHR P Pull blanking plug and BPV 09:00 11:00 2.00 COMPZ CASING DHEO P RU and test 7" casing and IBP to 3000 PSI. Chart for 15 min. held OK. 11:00 12:00 1.00 COMPZ FISH OTHR P MU landing jt. BOLDS. Unland hanger and pull to rig floor. Up wt 50K. Break out han er and landin ~t. i~<~c~~, ' cif 15 [ ~ i Time Logs Date From To Dur S. De th E De th Phase Code Subcode T Comment 12:00 16:00 4.00 3,045 0 COMPZ FISH PULL P POOH la in down 2 7/8" 511 H dril workstrin . 16:00 16:30 0.50 0 0 COMPZ FISH OTHR P Set Wear Ring. 16:30 17:00 0.50 0 0 COMPZ FISH PULD P Prep rig floor for BHA run # 1. 17:00 22:30 5.50 0 1,717 COMPZ FISH TRIP P RIH wit MS c tter, 12 -3 1/8"drill collars on 2 7/8" PAC Drill Pipe, running slow thru tight spot, obtained torque parameters at 500' and 1,000', re-set drilling torque on top drive to 3,500 ft/Ibs, with 800 ft/Ibs at 1,000' no pump, cont single in hole to 1,675', break circ and engage knives, slack off and locate 7" collar at 1,699', shut down pump and slack off to 1,717', u wt 50K -down wt 48K. 22:30 00:00 1.50 1,717 1,717 COMPZ WELCTI OTHR P RU circ line from OA to kill tank, bleed 100 psi off OA for 7" csg cut through 2" lines while rack and tally 3 1/2" work strin . 10/19/2008 Cut 7" csg at 1,717', POOH LD 2 7/8" work string, circulate hot seawater down the IA up the OA to kill tank, ND tbg head and lift BOP stack, remove tbg head, spear 7" csg, PU and remove slips and packoff, re-set BOP stack on well head, POOH LD 7" cs . 00:00 00:30 0.50 1,717 117 COMPZ WELCTI OTHR P Cont bleed down OA to kill tank. 00:30 02:00 1.50 1,717 1,717 COMPZ FISH CPBO P Break circ at 4 bpm - 3,000 psi and cut 7" casing, saw slight flow from OA with pump on, shut in on DP, pumped 5 bbls down workstring and u the OA, ood flow. 02:00 02:30 0.50 1,717 1,717 COMPZ FISH OTHR P Blew down circ line to kill tank and to drive. 02:30 05:00 2.50 1,717 0 COMPZ FISH PULD P POOH LD 2 7/8" work string from 1,717', LD cutter. 05:00 05:30 0.50 0 0 COMPZ FISH CIRC P Line up on kill line and pump hot sea water down the 7", out the IA to kill tank 3 bpm - 100 psi. Pumped 50 bbls and fluid started cleaning up, um ed total of 90 bbls to clean u . 05:30 06:00 0.50 0 0 COMPZ FISH OTHR P Blow down circ lines to kill tank, drain stack, check OA for flow. 06:00 10:30 4.50 0 0 COMPZ CASING NUND P Pull wear ring. ND BOPE & tubing head, remove tb head. 10:30 14:00 3.50 0 0 COMPZ CASING NUND P MU DSA. Set stack back on casing head and NU. Load all casing handlin tools to ri floor. 14:00 15:00 1.00 0 1,717 COMPZ CASING OTHR P MU Spear for 7" on one jt 3 1/2" drill pipe. Pull casing and emergency slips to rig floor. Max pull 200K. LD s ear and 1st 't 7' casin . 15:00 22:00 7.00 1,717 0 COMPZ CASING OTHR P POOH laying down 7" casing, numbering each jt for later identification during inspection. LD 43 and 1/2 joints for ~ total length of 1,686.75'. Recovered 17 cent. uideds. ~~ _ -~ ~a~~ ~ gat 1 r~ r Time Lomas Date From To Dur 5 Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 COMPZ CASING OTHR P Number and strap csg jnts, off load pipeshed, clean rig floor, RD csg tongs, break spear out of csg jnt, off load Baker cuttin tools. 10/20/2008 RU and run 9.625" caliper on slickline from 1,717' to surface, PU RIH with 7"dress-off mill assembly on 3 1/2" workstring, POOH and PU RIH with 7" packoff overshot, attempt to RIH but ran into tight spot at 217', POOH MU BHA #4 (8.5" string mill) RIH and mill 9 5/8" csg from 218' to 258', POOH for 8.5" string mill and found bum er su to be twisted off, call and wait on fishin tools. 00:00 01:00 1.00 0 0 COMPZ CASING OTHR P Cont off-load Baker tools and clean ri floor. 01:00 05:00 4.00 0 COMPZ EVALWE OTHR P PJSM, spot slickline unit, RU and load caliper tools, round trip with 9.625" csg caliper and GR/CCL memory tools to 7" PDS csg stub at 1,717', verify data download, RD slickline. Had a 5" piece of centralizer come OOH stuck on caliper tool. Loading new 7" csg in pipeshed while logging, drifting csg to 6.151". 05:00 07:00 2.00 0 0 COMPZ FISH MILL P Finish loading 7" casing in pipe shed. Service to drive. 07:00 09:00 2.00 0 218 COMPZ FISH MILL P MU & RI_ H BHA # 3 /8 ~" race_nff . shoe on 3.5" workstring. Tagged up @ 217', rotated and made 1' at 60 m, rotating torque 1,000 ftllbs. Max Rotating torque 2,700 ft/Ibs, max rpm 100, pumped 5 BPM @ 70 psi. Up wt 40K Dwn wt 40K Rot. wt 40K. 09:00 10:00 1.00 218 0 COMPZ FISH TRIP P POOH & LD 8.5" Dress-off shoe. 10:00 15:30 5.50 0 248 COMPZ FISH MILL P MU &RIH BHA # 4 with 8.5" Watermelon Mill on 3.5" workstring. Tagged at 218' Rotate @ 60 RPM, Up 40 K, Dn 40 K .Milled thru tight spot from 218' to 229' broke free. Reamed down to conne ion 248'. Pumping @ 5 BPM w/50 psi, full returns and ettin metal shavin s. 15:30 20:00 4.50 248 258 COMPZ FISH MILL P Made connection and reamed down to next ti ht s of cil 257'. Rotate 60 RPM, Up wt 40K Dwn wt 40K Rot. wt 40K. Pumping @ 5 BPM w/50 psi, full returns and still getting metal shavings over magnet. Off bottom torque 1,150 ft/Ibs, on bottom torque 7,500 ft/Ibs, makin no foota e. 20:00 21:00 1.00 258 0 COMPZ FISH TRIP P Blow down top drive, load new mill in pipeshed, PJSM, CO spinners, POOH and BHA #4 was twisted off at bum er sub. Left 1.6' of bum ersub, 1.79' x-o, 6.27' strip mill and 1.35' bull nose remain in hole at 258'. 21:00 00:00 3.00 0 0 COMPZ FISH WOEO T Call and wait on 8 1/8" x 3 3/4" overshot to be delivered to rig. Service and clean ri . ~~~® a ~ar~~ 3 ~t 15 i Time Logs. Date From To Dur S, Deptlt E. Depth Phase Code Subcode T Comment 10/21/2008 za hr Summary Fish out BHA # 6 (8 1/8" OD OS) and BHA # 4 (8.5" string mill), RIH and cont milling 9 5/8" csg with BHA # 10 6 3/4" strip mill and bull nose to 495' 00:00 02:00 2.00 0 258 COMPZ FISH WOEQ T Cont waiting on overshot and new bumpersub, cont cleaning rig, bring new tools in house. 02:00 05:30 3.50 258 0 COMPZ FISH FISH T MU BHA #5 (8 1/8" overshot) and RIH to 258', engaged fish, had indication of 3,000# overpull, blow down top drive, POOH. No fish, RIH same overshot. 05:30 06:00 0.50 0 248 COMPZ FISH FISH T RIH with same overshot with cutrite in guide shoe to dress up top of fish. Ran to 248'. Break circ 5 BPM @ 50 psi. Up wt 43K dwn wt 43K ROT wt 43K RPM 60. Attempt to engage fish. Max for ue 4500 fUlb. 06:00 07:00 1.00 248 0 COMPZ FISH PULL T Torque dropped off. SD monitor well, static. POOH w/BHA #6 (overshot). Bum er sub broken off at same spot as 1st Bum er Sub. 07:00 07:30 0.50 0 0 COMPZ FISH PULL T LD bumpersub &jars. 07:30 08:30 1.00 0 0 COMPZ FISH OTHR T Checked Top Drive torque settings and gauges. Adjusted max torque on Top Drive from 9000 ft/Ibs to 7000 ft/Ibs. Check out crown-o-matic, Slip and cut drillin line. 08:30 10:00 1.50 0 0 COMPZ RIGMNT SVRG P Slip and cut drilling line, while waiting on fishin tools from Baker in DH. 10:00 12:30 2.50 227 0 COMPZ FISH FISH T Unload fishing tools, PJSM. PU BHA # 7 consistin of 8 1/8" overshot, jars, 6 4 3/4" drill collars and RIH tagged @ 227'. Up wt 42K, Dwn wt 42K, ROT 42K. Attemt to get overshot down to fish @ 239'. Rotated down 7' and stacked 10K, stopped. POOH with no fish and inspect overshot. Guide lip on overshot ground down and gouges in side of overshot. 12:30 14:00 1.50 0 COMPZ FISH PULD T Break down BHA #7 and wait on tools. 14:00 16:00 2.00 COMPZ FISH WOEO T Wait on Fishing tools. 16:00 17:00 1.00 0 242 COMPZ FISH WOEO T Unload new fishing tools. PJSM. MU BHA # 8 consisting of 6 3/8" overshot. RIH, up wt 40K, dwn wt 40, tagged fish @ 242', attempted to swallow fish. 17:00 18:00 1.00 242 0 COMPZ FISH TRIP T POOH f/ 199' w/ BHA #8 no fish. La down 6.375" OD Overshot. 18:00 19:00 1.00 0 0 COMPZ FISH WOOR T Call WO engineer and discuss o tions. Clean work area. 19:00 19:30 0.50 0 0 COMPZ FISH TRIP T MU bull nose and RIH on DP to 242' and set down. Pooh w! same. 19:30 20:00 0.50 0 244 COMPZ FISH TRIP T MU BHA # 9 - 6.375" Overshot w/ 4.75" Grapple and control. RIH on DP to 242' and work down to 244' I 1 I Time Low __ - -- -- - __ - - - -_. ------ Date From To Dur S_ Depth E_ De th Phase_ Code Subcode T Comment 20:00 20:30 0.50 244 0 COMPZ FISH TRIP T POOH and recovered BH (8 1!8" OD Overshot) -release off fish and laid down. 20:30 21:00 0.50 0 250 COMPZ FISH TRIP T RIH w/ 6.375" OD overshot on DP to 246' and work down to 250' and en a e fish 21:00 21:30 0.50 250 0 COMPZ FISH TRIP T POOH w/ 5k overpull and recovered BHA #4 8.5" OD strin mill . 21:30 23:00 1.50 0 0 COMPZ FISH OTHR T Break down Fishing tools and offload same. 23:00 23:30 0.50 0 204 COMPZ FISH PULD P MU BHA #10 - 4.75" OD Bull nose, 6.75" OD string mill, 3 - 4.75" OD DC's, 4.75" OD Fishing Jars, 3 - 4.75" OD DC's. 23:30 00:00 0.50 204 495 COMPZ FISH MILL P Ream thru f/ 204' to 495' @ 60 rpm's w/ 800 ft/Ibs. free torque and 2,500 ft/Ibs. milling torque in various spots. Circulating @ 5 bpm @ 40 psi. 40k u wt, 40k do wt, 40k Rot wt. 10/22/2008 Continue to single w/ DP f/ 495' t! 1,717'with BHA #10 (6 3/4" string mill and bull nose). POOH CO mills to 8.25" and 8.50" strip mill, millin f/ 220' U 500'. Slide from 500' to 1,717' and CBU. 00:00 01:30 1.50 495 1,717 COMPZ FISH MILL P Continue to ream down from 495' to 1,717' and to to of 7" cs stub. 01:30 03:00 1.50 1,717 1,717 COMPZ FISH CIRC P Circulate BU and visc up hole volume. circulating @ 6 bpm @ 150 si. 03:00 05:00 2.00 1,717 204 COMPZ FISH TRIP P POOH f/ 1,717' to 204' w/ DP & 6 .75" strip mill. 05:00 06:00 1.00 204 0 COMPZ FISH PULD P Stand back 4.75" OD DC's and lay down fishing jars and 6.75" OD string mill. 06:00 09:30 3.50 0 218 COMPZ FISH PULD P MU BHA#11 consisting of 8 1/4" string mill, 1- 6 1/4"drill collar, 8 1/2" Watermelon Mill, 2 - 6 1/4"drill collar, Jars, 3 - 6 1/4" drill collars. 09:30 13:30 4.00 218 251 COMPZ FISH MILL P RIH and to ed ti ht s of 220:. Up wt 50K Dwn wt 40K, ROT wt 47K @ 60 RPM, WOB 3K torquing up. Start ettin cla and sand back in returns. Continued to mill to 251'. 13:30 14:00 0.50 251 251 COMPZ FISH OTHR P PU and stand back 1 stand of drill pipe. Adjust Top Drive Torque from 7000 ft/Ibs max to 9700 fUlbs max. 14:00 23:00 9.00 251 500 COMPZ FISH MILL P Increased RPM to 105 RPM able to put 5K WOB without torquing up, continue to mill from 251' to 500'. 3k ft/Ibs. free torque, 7k ft/Ibs. highest milling torque. Circulating @ 5 bpm @ 50 psi. 57k up wt, 55k do wt, 56k Rot wt. w/ 1-2k WOM. 23:00 23:30 0.50 500 1,717 COMPZ FISH MILL P RIH f/ 500' to 1,717' w/ no snags. 23:30 00:00 0.50 1,717 1,713 COMPZ FISH CIRC P CBU @ 6 bpm @ 160 psi. ~ 3~,; ~ o~ 'i 5 Time Logs - ---- Date From To_ Dur S D~th _E,_Depth Phase Code Subcode T Comment _ 10/23/2008 24 hr summary Continue to CBU till clean. POOH and attempt to slide thru f/ 220' to 500' till cleaned up. Laydown BHA #11 MU BHA #12 (7" Dress off shoe) RIH t/ 217' and set down. attempt to work thru w/ no luck. POOH and laydown BHA. PU and MU BHA #13 (8.5" mills) RIH and tag @ 222' and ream down to 440' then slide to 502'. Back ream back to 300'. 00:00 01:00 1.00 1,713 1,713 COMPZ FISH CIRC P Continue to CBU and Circ clean @ 6 b m 160 si. 01:00 01:30 0.50 1,713 1,713 COMPZ FISH OTHR P Monitor well 01:30 02:00 0.50 1,713 412 COMPZ FISH TRIP P POOH f/ 1,713' t/ 412'. 02:00 07:00 5.00 412 220 COMPZ FISH MILL P Ream tight spots f/ 412' to 220'. Main tight spots @ 400' - 430'; 383' - 395'; 315' - 365' bull nose de th. 07:00 09:00 2.00 220 0 COMPZ FISH TRIP P POOH and la down BHA #11. Gua ed 8 1/2" mill, 5%wear. 09:00 10:30 1.50 0 0 COMPZ FISH TRIP P MU BHA #12 consisting of 8 1/2" Washover Dress Off Shoe, Washover boot basket, 3 - 4 3/4"drill collars, jars, 3 - 4 3/4"drill collars on 3 1/2" drill i e. 10:30 11:00 0.50 0 217 COMPZ FISH MILL P RIH, to ed up @ 217'. 40K up wt, 40K down wt Rot 5 RPM free torque 2200 fUlb. 3100 ft./Ib on bottom. Pumped 2 BPM @ 60 psi. Could not work down. 11:00 12:00 1.00 217 0 COMPZ FISH PULD P Blow down Top drive. POOH with BHA # 12 and la down same. 12:00 14:30 2.50 0 214 COMPZ FISH PULD P PU & MU BHA #13 consisting of Bull nose, 8 1/2" Smooth OD String Mill, 8 1/2" Rough OD String Mill, 3 - 6 1/4" Drill Collars, Jars, 3 6 1/4" Drill Collars on 3 1/2"drill i e. 14:30 00:00 9.50 214 300 COMPZ FISH MILL P RIH, tagged @ 222' bull nose depth. Up wt 50K Dwn 45K Rot wt 48K, Free Rot torque 3000 ft/Ibls. 90 RPM, Pump 5 BPM @ 50 psi., reamed down thru ti ht s ots 214', 234', 240', 259', 272' bull nose, depth. w/ 3,800 to 6,200 fUlbs of torque. Continue to ream down to 440' and slide to 502'. Back ream up to 300'. w/ 3,500 ft/Ibs of torque. Was able to slide thru from 300' to 502' 2 to 6k wt loss. 10/24/2008 Continue to Back ream f/ 300' to 210'and attempt to slide thru f/ 214' to 300' till cleaned up 2- w/ 8 1/2" mills. Laydown BHA #13 MU BHA #14 (7" Dress off shoe) RIH t/ 1,717' and Dress off 7"CSG Stub. POOH. RU Slickline RIH w/ 9.625" CSG cali er tool w/ GR/CCL to 1,717'. RD slickline. RIH w/ 7" 26# BTC to 1,713' 00:00 03:30 3.50 300 210 COMPZ FISH MILL P Continue to back from 300' to 210', and slide thru 300'. 03:30 04:30 1.00 210 0 COMPZ FISH PULD P POOH from 210' and lay down BHA #13 (8.5" Rough OD and 8.50" Smooth OD mills 04:30 06:30 2.00 0 214 COMPZ FISH PULD P PJSM, MU BHA consisting of 8 1/2" Dress off Shoe for dressing up end of 7" stub 1717'. _. _ ~~ P~~~ ~ oF't~ l Time Logs ----- Date_ From To_ Dur S DeAth E_Depth Phase Code Subcode _ T Comm_e_nt____ ___ 06:30 10:00 3.50 214 1,724 COMPZ FISH MILL P RIH and to ed lightly t~ 217'. Rotated thru from 217' to 500'. Continue in hole to 1571'.: Established circulation pumping 5 BPM w/140 psi. Washed down to top of 7"and tagged @ 1717'. Dressed u to of 7" from 1717' to 1724'. 10:00 10:30 0.50 1,724 1,724 COMPZ FISH CIRC P PU to 1713'. Pumped 35 bbl high vis sweep 5 BPM w/140 psi. Circulated until swee return and hole cleaned. 10:30 14:30 4.00 1,724 0 COMPZ FISH PULD P Blow down TD. POOH standing back drill pipe and laying down BHA. Load out fishin tools not needed. 14:30 17:30 3.00 COMPZ CASING OTHR P PJSM. RU Slickline. Round trip PDS 9.625' casing caliper & GR/CCL memory tools to 7" stub @ 1717". RD Slickline. 17:30 19:00 1.50 COMPZ CASING OTHR P PJSM. RU floor equipment to run 7" 26#CSG 19:00 22:30 3.50 0 1,713 COMPZ CASING PUTB P PJSM. RIH w/ 7" CSG Patch, 10' x 7" 26# CSG pup jt., HES ES cementer, and 42 jts 7" 26# BTG CSG to 1,713'. 22:30 00:00 1.50 1,713 1,713 COMPZ CASING OTHR P RU Big bails. RU HES Cement head. 10/25/2008 RU CMT Head, Engage 7" CSG stub w/ CSG patch (failed) POOH w/ 7" 26# BTC CSG. RIH w/ 6 1/8 String mill to 2,200' and POOH. MU and RIH w/ CSG BO tool and BO 7" cs stub 1,737'. 00:00 01:00 1.00 1,713 1,713 COMPZ CASING OTHR P Insert 7"wiper plug and continue to RU CMT head and lines. 01:00 02:30 1.50 1,713 1,720 COMPZ CASING RPTH P Attempt to engage grapple, failed, RD cmt head and MU TD. Circulate @ 4 bpm @ 80 psi and work over stub, still no enga ment oi• pressure increase. 75k u wt, 65k do wt. 02:30 03:00 0.50 1,720 1,720 COMPZ CASING CIRC P Circulate BU @ 4 bpm @ 80 psi. 03:00 06:00 3.00 1,720 0 COMPZ CASING OTHR T POOH la in down 7" 26# L-80 BTC cs and ins ect cs atch. 06:00 08:00 2.00 0 0 COMPZ CASING OTHR T PJSM, C/O Bales, RU floor to run Drill Pi e. 08:00 11:30 3.50 0 2,200 COMPZ CASING OTHR T PU & MU BHA # 15 consisting of 4 3/4" bull nose, 6 1/8" string mill, jars and 12 - 4 3/4"drill collars. RIH on 3 1/2' drill pipe, slid into 7" @ 1717' easy with no problems. Ran string mill down to 2200'. 11:30 12:30 1.00 2,200 2,200 COMPZ CASING OTHR T Circulate @ 2200' to clean up hole. Pum ed 7 BPM w/300 si. 12:30 14:00 1.50 2,200 389 COMPZ FISH TRIP T POOH to drill collars, standing back drill i e 14:00 16:00 2.00 389 411 COMPZ FISH OTHR T PJSM. Start making up BHA16 consisting of casing back off tools. While MU and torquing connection tool broke in to sli section. 16:00 19:00 3.00 411 411 COMPZ FISH WOEO T Break out and lay down wait on re lacement tool. e_ ee .~ -_ ~a~e 7 ref 15 ra • Time Logs - - ---- - --- Date _ From To Dur 5_Depth E. De th Phase Code Subcode T_ Comment _ 19:00 22:00 3.00 411 2,135 COMPZ FISH PULD T MU new upper slip section. RIH f/ 411' t/ 2,135' w/ upper slips @ 1,721' filling DP w/diesel to gain under balance too erate back off tool. . 22:00 00:00 2.00 2,135 2,100 COMPZ FISH CPBO PJSM. RU lines, Slack off to 2,145' w/ upper slip section @ 1,731' w/ 68k up wt, 62k do wt. Set lower slip section @ 1,500 psi. Slack off 15k for DC's hanging wt. Slack off 4" to close power section. Pressure up to 3,400 psi and function tool of started @ 360 psi / 3,600 ft/Ibs of torque. Continue to cycle tool for a total of 12 cycles ! 4.5 full revolutions. RD High pressure test pump lines. Pull to 2,100' and release BO tools. 10/26/2008 POOH and found BO Tool failed. Conduct weekly BOP test. MU and RIH w/ CSG BO tool # 2 and BO 7" csg stub 1,740'. RIH w/ S ear 00:00 01:30 1.50 2,100 2,100 COMPZ FISH OTHR T PJSM. RU and Shear out pump out sub @ 2,250 psi. Circulate diesel out of the hole 6 b m 160 si. 01:30 02:30 1.00 2,100 422 COMPZ FISH TRIP T BD lines, POOH f/ 2,100' to 422'. Break out BO tools and found top sli section not to have sheared.). Continue to lay down BO tool. Stand back DC's. 02:30 04:00 . 1.50 422 0 COMPZ FISH PULD T Break out BO tools and (found top slip section not to have sheared.). Continue to lay down BO tool. Stand back DC's and lay down 6 1/8" String mill 04:00 05:30 1.50 0 0 COMPZ WELCTL OTHR T Wash stack w/ swiule stick @ 190 spm @ 60 psi ,Blow down top drive and drain stack. 05:30 06:00 0.50 0 0 COMPZ WELCTL OWFF T Monitor well, static. 06:00 07:00 1.00 0 0 COMPZ WELCTL OTHR T RU line from 9 5/8 Surface casing tq tiger tank for monitoring while conductin B P test. Set Test lu . 07:00 12:30 5.50 0 0 COMPZ WELCTL BOPE P Conducted weekly BOPE test on 13 5/8" stack w/2.875" x 5 1!2" variable rams top and bottom. PT BOP rams to 250/3000 psi for 3 1/2" & 4 1/2" pipe and annular to 250/2500 psi. Witnessing of test waived by Jeff Jones 10/25/08 @ 20:35 hrs. RD test e ui ment. 12:30 17:00 4.50 0 2,128 COMPZ FISH TRIP T PJSM, PU BHA # 17 consisting of 7" casin back-off tool and RIH filling with diesel every stand. Set the bottom of the top anchor @ 1732, the top of the bottom anchor @ 1752' straddlin casin collar 1737'. ~ ~~ t rage ~ ~t 15 Time Logs __ _ _ _ __ Date From To Dur S De th E De th Phase Code Subcode T Comment 17:00 18:30 1.50 2,128 2,128 COMPZ FISH CPBO T Stab head pin with hoses connected to test pump. 65K Hanging wt. Press. to 1000 psi, slack off 10K to 55K. Bleed press off wait 2 min. Slack off 4". Press. up to 3500 sheared out at 1700 psi. Slack off, bleed press. wt 3 min. Pumped up, broke @ 2600 -pipe turned 1/2 turn. Repeated this step until would not press any more and quit turning. Made 4.5 total turns. 18:30 20:00 1.50 2,128 2,128 COMPZ FISH CIRC T Shear pump out sub, circulate out diesel to kill tank @ 8 bpm @ 250 psi, 4 bpm @ 130 psi. Blow down lines. Monitor well 20:00 21:00 1.00 2,128 405 COMPZ FISH TRIP T POOH f/ 2,128' to 405' 21:00 21:30 0.50 405 0 COMPZ FISH PULD T LD back off tool. Rack back DC's 21:30 22:00 0.50 0 26 COMPZ FISH PULD T MU BHA #18 consisting of spear w/ 6.220" NOM. grapple, X-O sub, DP pup jt, 6.75" OD String mill for stop sub, Lub. Bum er sub. 22:00 00:00 2.00 26 1,706 COMPZ FISH TRIP T RIH w/ BHA #18 to 1,706' on DP 10/27/2008 recover csg stub. MU and RIH w/ 7" CSG screw in assy to 216' not able to work past. POOH and remove Skirted screw in sub, replace w/ notched CSG Cplg. RIH to 214' not able to work past. POOH and change design. RIH to 214' not able to work past. MU and RIH w/ BHA #19 (8.5" OD String mills) RIH and redress f/ 214' to 500' and back ream out the same. POOH and RIH w/ 7" CSG to 1,740' and Screw in. 00:00 00:30 0.50 1,706 1,740 COMPZ FISH FISH T Engage stub @ 1,730' w/grapple and back out 7" casing stub (a)_ 1 740' 00:30 01:30 1.00 1,740 37 COMPZ FISH TRIP T POOH f/ 1,740'to 37' 01:30 02:30 1.00 37 0 COMPZ FISH PULD T POOH and release off fish, Recover 22' of 7" Casing w/ cplg leaving top o~ casing stub @ 1,740'. 7" CSG stub was hen skinned by dressing mill ass the fut- 7'. 02:30 03:00 0.50 0 0 COMPZ CASING OTHR T RU CSG equipment 03:00 03:30 0.50 0 0 COMPZ CASING SFTY T Held PJSM w/ crew, Csg tong op, and HES CMTR. 03:30 05:00 1.50 0 216 COMPZ CASING PUTB T MU and RIH w/ 8.375" OD Cut lip skirted screw in sub w/ cplg down, 4' x 7" 26# L-80 BTC Pup Jt, 10' x 7" 26# L-80 BTC Pup Jt, HES ES CMTR, 5 Jts 7" 26# L-80 BTC and set down @ 216' not able to rotate thru. 05:00 06:30 1.50 216 0 COMPZ CASING OTHR T POOH w/ 8.375" OD Cut lip skirted screw in sub w/ cplg down, 4' x 7" 26# L-80 BTC Pup Jt, 10' x 7" 26# L-80 BTC Pup Jt, HES ES CMTR, 5 Jts 7" 26# L-80 BTC. Inspect Cut lip. Flared out on end. Time Logs _ _ __ Date From To Dur S De th E De th Phase Code Subcode T Comment 06:30 08:00 1.50 0 214 COMPZ CASING OTHR T MU 7" Collar w/small cut lip and RIH on 7" casing. Stacked out at same place 214'. Attempted to work by bad s of wino luck. 08:00 09:00 1.00 214 0 COMPZ CASING OTHR T POOH f/214' LD 7" casing & remove cut lip collar damaged end and threads. 09:00 11:30 2.50 0 214 COMPZ CASING OTHR T Beveled new 7" collar w/small cut lip MU on end of 7" casing. RIH, stacked out at 214' a ain. Attem ted to work thru bad spot but could not et to collar to o thru. POOH LD 7' casin . 11:30 13:30 2.00 0 0 COMPZ CASING OTHR T RD casing equipment. RU floor to run DP. Load pipe shed with two string mills and MU. RIH w/one 8 1/2" smooth OD string mill on bottom and one 8 1/2" rough OD string mill with 'ars on 3 1/2"drill i e. 13:30 16:00 2.50 0 500 COMPZ CASING OTHR T RIH to 214'. UP wt 45K Dwn wt 45K Rot wt 45K. Max Torque 2250 ft/Ibs. Rotate and o en hole down to 500' hitting tight spots @ 216' to 230', 267' to 285', 313' to 318' and 420' to 425'. Back reamed out to 211'. 16:00 17:00 1.00 500 0 COMPZ CASING OTHR T POOH laying down BHA. 17:00 17:30 0.50 0 0 COMPZ CASING OTHR T RU CSG Equipment. 17:30 18:00 0.50 0 0 COMPZ CASING SFTY T Held PJSM w/ crew, CSG Crew & Fishin tool hands. 18:00 22:00 4.00 0 1,734 COMPZ CASING PUTS T PU and MU and RIH w/ 7" cut lip CSG Coupling, 10' x 7" 26# L-80 BTC Pup jt, HES es CMTR, 1 jt 7" 26# L-80 BTC, 20' x 7" 26# L-80 BTC Pu 't, 41 'ts 7" 26# L-80 BTC. 22:00 23:00 1.00 1,734 1,734 COMPZ CASING OTHR T MU 10' x 7" 26# L-80 BTC Pup jt w/ X-O, 3 1/2 DP pup jt to top drive. Screw into 7" CSG string and set torque 8,000 ft/Ibs (which was the ave. over 15 jts) Break circulation and establish parameters 4 bpm @ 80 psi, 15 rpm's @ 1,700 ft/Ibs free torque. 76k up wt, 63k do wt & ROT wt 72k. 23:00 00:00 1.00 1,734 1,740 COMPZ FISH OTHR P Screw into 7" CSG @ 1,740' w/ 14.5 rotations and torque up to 8,000 ft/Ibs. Work torque downhole @ 5k osw, 5k slack off, 10k osw, 10k slack off, 15k osw, 15k slack off, 20k ows, 20k slack off. 10/28/2008 PT CSG to 2,500 psi for 15 minutes. Shear out ES CMTR and circ hot sea water. RU Sch-umberger and cmt 7" CSG in place. WOC. ND BOPE and set slips 50k osw. Dress stub and set pack off. Install TBG head and orient. NU TBG head. 00:00 00:30 0.50 1,740 1,740 COMPZ CASING DHEO P Pull 50k osw to 125k and PT 7" CSG to 500 si. Remove drive sub Ass . 00:30 03:00 2.50 1,740 1,740 COMPZ CASING OTHR P RU CMT head and teast hoses to PT CSG and shear out ES CMTR. ~~ ~~s~e ~~ c~t'[~ Time Logs - -- - - -- Date From To Dur S. Depth E. De th Phase Code Subcode T Comment _ 03:00 03:30 0.50 1,740 1,740 COMPZ CASING DHEO P _ PT 7" CSG to 2,500 psi hold and chart for 15 min. Bleed off. 03:30 04:00 0.50 1,740 1,740 COMPZ CASING DHEO P Pressure u to 3,400 si and o en ES CMTR. 04:00 07:00 3.00 1,740 1,740 COMPZ CASING CIRC P CBU @ 5 bpm @ 220 psi. Switch to 127 deg Sea water and swap hole over f/ viscousified sea water. Continue to Circulate hole w/ heated sea water till cmt crew arrives on location. 07:00 10:00 3.00 1,740 1,740 COMPZ CEMEN" CIRC P RU Schlumberger and PT lines @ 3,200 psi. Mix pump and pump 81.5 bbls 15.7 ppg Articset 1 slurry. drop wiper plug and Follow w/ 2 bbls of slurry. Displace w/ 27.4 bbls 8.5 ppg seawater. SD and removed 3" 750 psi ball valve and installed VR Plug in annulus nipple. Filled stack back up w/ CMT retarder and 8.5 ppg sea water. Continued to displace w/ 40 bbls 8.5 ppg seawater. Closed "es" cmtr @ 1,650 psi and placed an -._ extra 200 psi above w/ 2 bbls for a tota169.5 bbls pumped.. Bleed back 2 bbls "es" cmtr is shut, and 16 bbls was pushed ahead of wiper into the formation after annular valves were closed w/ 40 psi annular squeeze pressure. Annulus went on slight vacumn and later climbed back to 40 psi. Bled down pressure and washed out stack to clear an cmt. 10:00 13:00 3.00 1,740 1,740 COMPZ CASING WOC P Rig down cement head, unload tools and equipment. Change out bails on to drive. 13:00 15:30 2.50 1,739 1,740 COMPZ CASING NUND P PJSM, ND BOPE 15:30 00:00 8.50 1,740 1,740 COMPZ CASING OTHR P Set 7" casing slips, cut 7" casing, install pack off assembly. Set BOP down and pull stub. Remove adapter spool and cut csg stump. Install and orient TBG head and tree. Confirm orientation w/ 2A DSO (Kenny). Remove tree and NU TBG head. 10/29/2008 NU 13 5/8 BOP and Shell test TBG head and BOPE @ 3,000 psi for 15 min. MU and RIH w/ 6.125" Bit assy to 1,650' and drill out cmt f/ 1,667' to 1,725' and drill up wiper plug and chase to 1,733'. Then wash down to 1,846'. PT 7" csg to 2,500 psi and chart for 30 minutes. POOH and PU string magnet and RIH to 3,466' and dry drill on junk on sand plug. Circ. Sweep and POOH. MU and RIH w/ reverse circulating junk basket to 1,245'. 00:00 00:30 0.50 1,740 1,740 COMPZ CASING DHEO P Test Pack offs to 3,000 psi and hold for 15 minutes. 00:30 04:30 4.00 0 0 COMPZ WELCTL NUND P NU ROPE and Shell Test @ 3,000 psi and hold for 15 minutes. Notice was given to AOGCC @ 11:45 hrs on 10-28-08 was witness was waived by Jeff Jones @ 14:30 hrs on 10-28-08. ( L';~q~ ~ 1 cif 1 n • Time Logs ___ __ _____ Date From To Dur S _De~th E_Depth Phase Code Subcode T Comment __ 04:30 05:00 0.50 0 0 COMPZ DRILL OTHR P Install Wear ring. 05:00 06:30 1.50 0 0 COMPZ DRILL PULD P PU and MU BHA #20 6 1/8" Bit assy 06:30 08:00 1.50 0 1,667 COMPZ DRILL TRIP P RIH to 1650'. Up wt = 62K# down wt = 60K#. RIH and tag 3K# down at 1667'. PUH circulating 5 bpm @ 260 psi, RPM 80 at 1600 ft# of for ue. 08:00 11:30 3.50 1,667 1,846 COMPZ DRILL MILL P Washing down to 1725'. Worked hard for down to 1733'. Up wt = 62K#, down wt = 60K#. Wash down to 1846'. 11:30 12:00 0.50 1,846 1,846 COMPZ DRILL CIRC P Circulate 35 bbl high visc pill, 6 bpm 400 si. 12:00 13:30 1.50 1,846 1,846 COMPZ DRILL DHEQ P RU lines, test 7" casing to 2500 psi, charted for 30 min. RD lines. 13:30 14:30 1.00 1,846 0 COMPZ DRILL TRIP P POOH standing back DP, LD BHA 14:30 15:30 1.00 0 0 COMPZ DRILL PULD P Cleanout boot baskets. MU BHA #21 6-1/8 bit with strin ma net 15:30 17:30 2.00 0 3,429 COMPZ DRILL TRIP P RIH w/ string magnet and 6.125" Bit to 3,429' MD 80k u wt, 65k do wt. 17:30 18:00 0.50 3,429 3,466 COMPZ DRILL OTHR P Establish parameters and to u on sand 3 466' MD 18:00 19:00 1.00 3,466 3,468 COMPZ DRILL MILL P Dry drill @ 3,466' to 3,468' MD 19:00 20:00 1.00 3,468 3,463 COMPZ DRILL CIRC P Pick up to 3,463' and pump 20 bbl hi visc sweep @ 5 bpm @ 320 psi and chase w/ sea water @ 9 bpm @ 1,070 si. 20:00 21:30 1.50 3,463 394 COMPZ DRILL TRIP P Blow down Top drive. POOH f/ 3,463' to 394' 21:30 22:00 0.50 394 0 COMPZ DRILL PULD P POOH w/ BHA # 21 and clean string magnet. Recovered large quantity of millin sand small feces. 22:00 00:00 2.00 0 1,245 COMPZ FISH TRIP P RIH w/ BHA # 22 run #1 (Reverse circulating Junk Basket assy) to 1,245' 65k u wt, 53k do wt. 10/30/2008 Continue to RIH f/ 1,245' to 3,466' and core 2' and function RCJB. POOH and Clean RCJB and RIH w/Same till clean. RIH to 3,527' and wasn't able to find IBP @ 3,483. Swap hole over to 9.6 ppg KW Fluid. POOH and RU Slickline to RIH w/ OS. 00:00 00:30 0.50 1,245 3,425 COMPZ FISH TRIP P Continue to RIH f/ 1,245' t/ 3,425' 00:30 02:00 1.50 3,425 3,471 COMPZ FISH CIRC. P MU TD 3,425' and gather parameters and circulate thru tool. Drop ball and RIH t/ 3,466' and Tag sand. Rotate down 3' @ 50 rpms @ 3,000 ft/Ibs. Cycle pumps @ 8 bpm @ 1,800 psi. SD Pum sand BD TD. 02:00 03:00 1.00 3,471 371 COMPZ FISH TRIP P POOH f/ 3,471' 03:00 04:00 1.00 371 0 COMPZ FISH PULD P POOH w/ BHA #22 after run 1 break out finger baskets and remove junk from shoe. CO boot baskets. 04:00 05:00 1.00 0 371 COMPZ FISH PULD P MU and RIH w! BHA #22 run #2 ~~ Pao f'?cf'fa Time Logs _ _ __ _ ____ Date From To Dur S. De th E. De th Phase Code Subcode T Comment ____ 05:00 06:30 1.50 371 3,474 COMPZ FISH TRIP P RIH w/ BHA #22 run 2 on DP to 3325'. KU and wash down, tag at 3474. Swallow to 3479'. 06:30 07:30 1.00 3,474 0 COMPZ FISH TRIP P POOH with BHA #22 (run #2). Up wt = 85K#, down wt = 65K#. 07:30 09:00 1.50 0 0 COMPZ FISH PULD P Break junk basket. Filled mostly with sand and some small metal pieces (largest about 1" x 1 "). Clean magnet, covered with metal fines. Make u BHA #22 run #3 . 09:00 11:00 2.00 0 3,482 COMPZ FISH TRIP P PJSM. RIH tagged top of sand at 3478'. Swallow to 3482' 11:00 12:30 1.50 3,482 .3,482 COMPZ RIGMNT SVRG P Service crown, blocks, top drive. Inspect draw works and brake linka e. 12:30 14:00 1.50 3,482 0 COMPZ FISH TRIP P PJSM. POOH from 3482'. Up wt = 85K#, down wt = 65K#. 14:00 15:30 1.50 0 0 COMPZ FISH PULD P Break junk basket, 4 fingers missing from the catcher sub. No fill in junk basket. Metal fines on magnet (about 1/2 the amount of fines from previous run). Break and LD BHA. 15:30 17:00 1.50 0 0 COMPZ FISH WOOR T Clean rig floor while Waiting on decisions to be made on type of BHA to RIH. 17:00 18:00 1.00 0 12 COMPZ FISH PULD P Lay down jars, LBS and M_U BHA #23 6" OD production Poorboy TBG stub OS w/o shear screws in place and X-O to 3 1/2 IF. 18:00 21:00 3.00 12 3,527 COMPZ FISH TRIP P RIH w/ BHA #23 on 3 1/2 DP to 3,527' -not able to locate IBP @ ex ected de th of 3482'. 70k up wt, 63k do wt. 21:00 21:30 0.50 3,527 3,527 COMPZ WELCTI CIRC P Circulate out 8.6 ppg brine and replace w/ 9.6 ppg brine 8 bpm @ 800 si. Blow down TD. 21:30 23:00 1.50 3,527 0 COMPZ FISH TRIP P POOH w/ 3 1/2 DP f/ 3,527' and LD BHA #23. 23:00 23:30 0.50 0 0 COMPZ FISH OTHR P Pull wear ring in preparation for Slickline. 23:30 00:00 0.50 0 0 COMPZ FISH SLKL P Held PJSM w/ HES Slickline and RU. 10/31 /2008 RIH w/ OS and engage fish @ 8,512' SLM and POOH. RIH w/ 5.98" OD Guage ring and locate stub @ 8,515' SLM. POOH. RIH w/ 5.98" OD LIB to top of stub. POOH and RD SL. RIH w/ DP and DC's. POOH laying down. PU and RIH w/ 4.5" Com letion strin to 2,252'. 00:00 00:30 0.50 0 0 COMPZ FISH SLKL P Continue to RU Slickline 00:30 03:00 2.50 0 0 COMPZ FISH SLKL P RIH w/ OS to 8,512' SLM and engage IBP, POOH and lay down the same. 03:00 04:30 1.50 0 0 COMPZ FISH SLKL P MU and RIH w/ 5.98" OD Gauge ring and tag 3 1/2 TBG stub @ 8,515' SLM. POOH w/ same. ®~ _~e ~ e a I Pace ~3 off ~~ Time Logs ~ _ Date From To Dur S. Depth E Depth Phase Code Subcode T .Comment ~I _ - - ---- 04:30 07:30 3.00 0 0 COMPZ FISH SLKL P MU and RIH w/ 5.98" OD LIB to 8,513' SLM. POOH w/Same. 07:30 13:30 6.00 0 0 COMPZ RPCOM OTHR P RIH with stands of 3-1l2" DP and DC to 3857'. POOH laying down sin les. 13:30 15:00 1.50 0 0 COMPZ RPCOM RURD P Swap handling equipment, pull wear ring. Prepare to RIH w/ 4.5" Com letion. 15:00 19:00 4.00 0 1,693 COMPZ RPCOM PULD P Held PJSM w/ crew and Packer service hand. MU and RIH w/ 4.5" Completion string to 1,693'. 47k up wt, 45k do wt. 19:00 23:00 4.00 1,693 1,693 COMPZ CASING OTHR P PJSM w/ Downhole Diagnostics and Freeze protect 7" x 9.625" f/ TOC @ 55' swap out 8.6 ppg brine for 9.6 ppg brine then pull off top 20' and top off w/diesel. 23:00 00:00 1.00 1,693 2,252 COMPZ RPCOM PULD P Continue to Rlh w/ 4.5" Completion f/ 1,693' to 2,252' 57k u wt, 54k do wt. 11 /01 /2008 Continue to RIH w/ 4.5" Completion from 2,252' to top of TBG stub and spot inhibited 9.6 ppg brine. Set PKR and Space out. Land hanger and PT TBG to 3k psi and IA to 3k psi. Shear out SOV. ND BOP and NU Tree. FP TBG x IA. and allow to u-tube. 00:00 07:00 7.00 2,252 8,458 COMPZ RPCOM PULD P Continue to RIH w/ 4.5" completion to 8458'. Up wt = 115K, down wt = 80 K 07:00 08:00 1.00 8,458 8,458 COMPZ RPCOM SFTY P Perform man down drill with KRU Fire De t. 08:00 13:30 5.50 8,516 0 COMPZ RPCOM HOSO P RIH to 8500'. Pump 50 bbl of inhibited 9.6 brine (1 % CRW 132), displace tubing with 130 bbl of 9.6 brine. Pumping 3 bpm @ 200 psi. Up wt = 115K, down wt = 85K. RIH, weight boobled at 8510'. Sat down at 8513' with 10K then released. Started taking weight at 8516' PU string wt and pull up 1' to 8515'. Pump to confirm over shot still engaged. Pumping 2 bpm @ 270 psi (previous 3 bpm @ 200 psi). Drop ball and rod. Pressure up to 2000 psi and set FHL packer. Pull out seal assembly from PBR with 15K# of overpull to release. Space out seal assembly 2.3'. Land han er. RILDS. ~'~€~~ i~~#'f~ ~~ Time Logs _ I Date From To Dur S. De th E. De th i'hase Code Subcode T Comment 13:30 16:00 2.50 0 0 COMPZ RPCOM DHEQ P PJSM. RU lines and pressure test tubing to 3000 psi 15 min, bleed down tubing to 2000 psi. Pressure test IA to 3000 psi 30 min. Bleed off la and tubing pressure. Pressure up IA and shear out SOV at 1500 si. 16:00 17:30 1.50 0 COMPZ RPCOM NUND P PJSM. Set BPV. ND BOPE. 17:30 19:30 2.00 COMPZ RPCOM NUND P Clean well head and install Tree. 19:30 20:00 0.50 COMPZ RPCOM SFEO P PT TBG hanger void to 5,000 psi for 15 minutes and PT Tree to 5,000 psi for 15 minutes. 20:00 21:00 1.00 COMPZ RPCOM OTHR P RD and Bleed down all test e ui ment, Pull TWC 21:00 00:00 3.00 COMPZ RPCOM FRZP P Held PJSM w/ LRS. Pump 75 bbls down IA and shutdown. Break off and tie TBG to IA and allow to u-tube 11/02/2008 Continue to U-tube. Lubricate in HBPV. Bleed off tree and lay down Lub ricator. Bleed off tree and dress same. RDMO. Clean and clear cellar 00:00 01:00 1.00 COMPZ RPCOM OTHR P Continue to U-tube. SWI 140 psi on TBG and IA. 01:00 02:00 1.00 COMPZ RPCOM OTHR P Load lubricator and lub in HBPV and set. Bleed off tree and RD Lubricator. Change time back 1 hr for da li ht savin s time. 02:00 02:30 0.50 COMPZ MOVE DMOB P Pull rig off 2A-05 and clear and clean cellar. Final Shut in Pressures 140 psi tbg, 140 psi IA and 50 psi OA Release Nordic Rig 3 @ 2:30 hrs on 11- - ~ ~~€, 15 t~'~ 15 VV~~~ L T°/~.4/~S~l/TT~4L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 • a ~~'~ RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 24-0ct-08 2A-05 1 Report / EDE 2] Correlation Log 24-Oct-08 2A-05 1 EDE U~~ ~~~~~ ~ ~~-oa3 t ~~~ Signed Print Name: ~~ri,; ~I-iu.o ~/~,.~i~ 50-103-20030-00 50-103-20030-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~c3s~nc~;or~rn~~a,y9a~.aam WEBSITE:~nnrr~v.l~esna~~~at~.carr~ t--.` C:\Documertis and Settings\Ownet\Desktop\Transmit_Conoco.doc .T s Memory Mufti-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-05 Log Date: October 24, 2008 Field: Kuparuk Log No.: 7277 State: Alaska Run No.: 5 API No.: 50-103-20030-00 Pipet Desc.: 9.625" 36 Ib. J-55 Top Log Intvl: Surface Pipet Use: Surface Casing Bot. Log Intvl: 1,696 Ft. (MD) Inspection Type : Post Mill Out Casing Inspection COMMENTS This caliper data is tied into dee top of the 9,625" Surface Casing at 0'. This log was run to assess the condition of the 9.625" surface casing following mill out operations to ' determine the efficacy of obstruction removal since the last caliper log. This is the fifth time a PDS caliper has been run on this well and the second time the 9.625" surface casing has been logged. A comparison of the current and previous log (October 19, 2008) indicates an increase in ' intemal diameters recorded throughout the logged interval, particularly the interval of deformation due to severe buckling from 180' to 400', 3-D log plots of the re-centered and ofF center caliper recordings of the entire log interval are included in this report. ' Deposits (likely mill out debris} dragged up hole by the caliper fingers impair the movement of multiple adjacent fingers from 1,500' to -500', before the fingers tracked over the debris. As a result, reported minimum diameter information for this interval is likely smaller than the actual diameter of the surface casing. A Minimum Recorded Diameter Profile, illustrating the minimum recorded diameter on a joint-by joint basis, ' is included in this report. Holes due to mill wear are recorded in joints 5, 6 and 7, with additional mill damage from 20% to 62% wall ' thickness recorded throughout the remainder of the surface casing logged. Cross-sectional wall loss of 96% is recorded in the vicinity of the mill wear in joint 5 (195'), while debris restricts the measured I.D. to 7.19" (194'). ~~1` SIC' 4~ ~ 2D~$ MAXIMUM RECORDED WALL PENETRATIONS ' Holes due to Mill Wear (100%) Jt. 5 c~ 188 Ft. (MD) Holes due to Mill Wear (100%) Jt. 6 @ 219 Ft. (MD) Holes due to Mill Wear (100%) Jt. 7 @ 254 Ft. (MD) Mill Wear (62%) Jt. 10 @ 387 Ft. (MD) Mill Wear (46%) Jt. 8 @ 282 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' Mill Wear (96%) Jt. 5 cLD 197 Ft. (MD) Mill Wear (88%) Jt. 6 @ 225 Ft. (MD) Mill Wear (76%) Jt. 7 @ 273 Ft. (MD) Mill Wear (22%) Jt. 10 ~ 386 Ft. (MD) No other significant areas of cross-sectional wall loss (> 13%) are recorded throughout the surtace casing logged. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 7797 Phone: (28i) or (8IIu) 565-9QII5 Fax; (~31) 565-1369 E-maih PDSi~mei~~orylog.com Prudhoe Bay Field Office Phone; (9Q71 659-2307 Fax: {907) 659-231+ (~. c`O~l~ C~~o~ ~~ " T ~l MAXIMUM RECORDED ID RESTRICTIONS ' Deformation due to Buckling Minimum I.D. = 7.19" Jt. 5 cLD 194 Ft. (MD) Deformation due to Buckling Minimum I.D. = 7.48" Jt. 6 @ 228 Ft. (MD) Deformation due to Buckling Minimum I.D. = 8.26" Jt. 9 @ 322 Ft. (MD) ' Excluding the minimum diameters influenced by the impaired caliper fingers from -500' to _1,500', no other significant I.D. restrictions are recorded throughout the surface casing logged. Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witriess: R. Overstreet FroActive Diagnostic Services, Inc. j P.O. Box 1369, Stafford, TX 77497 Fhone: (281) or (888! 565-5085 Fax: (281) 565-1369 E-mail: PCS@memorylog.com ' Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: (907} 659-2314 U • • PDS Multifinger Caliper 3D Log Plot ~-.,, __ 5 Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-05 Date : October 24, 2008 Description : Defail of Caliper Recordings Across 9.625" Surface Casing After Mill-Out • to Mill Wear - T~ i ~. Joint 8 300 Severe Buckling - - - Joint 9 350 -- - - - - - -- Joint 10 Severe Buckling - Joint 11 400 --- 450 Joint 12 Joint 13 Impaired 500 - -- _. _ Fingers Joint 14 Impaired Fingers / Severe Buckling 550 Joint 1fi Impaired Fingers I Severe - -- - -_ Buckling 600 Joint 16 Impaired Fingers Severe Buckling __ _._ - - -_ -- • • Impaired 650 Fingers ! Severe Buckling - --- - --- _. Joint 18 Impaired - Fingers 700 Joint 19 I i d mpa re Fingers / Severe Buckling - 750 Joint 20 _ __ _ _ Impaired Fingers / --- Severe Buckling Joint 21 $00 Impaired Fingers / Severe - - - - -- -- Buckling -- --- Joint 22 Impaired 850 Fingers Joint 23 h i d - npa re Fingers 900 Joint 24 Impaired - Fingers - - 950 Joir>t 25 Impaired Fingers / Severe Buckling Joint 26 Impaired 1000 Fingers / Severe lJ • Joint 27 --- Impaired Fingers 1050 Joint 28 I i d mpa re Fingers / -- -- - Buckling - 1100 Joint 29 I i d mpa re Fingers / -- Buckling - 1150 Joint 30 Impaired Fingers Joint 31 1200 Impaired Fingers Joint 32 Impaired Fingers 1250 Joint 33 Impaired - Fingers 1300 Joint 34 Impaired Fingers 1350 Joint 35 I mpaired Fingers __ _ -- j1 • • Impaired 1400 Fingers Joint 37 Impaired Fingers 1450 Joint 38 Impaired Fingers _ --- 1500 Joint 39 Impaired Fingers -- 1550 Joint 40 __ Joint 41 1600 Joirrt 42 1650 Joint 43 _. Joint 44 Top of 7" 1700 Casin • ~ • PDS Multifinger Caliper 3D Log Plot L,,_ . Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-05 Date : October 19, 2008 Description : Detail of Off-Center Caliper Recordings Across Severely Buckled 9-5/8" Surface Casing • Severe Buckling / _ _ _- Holes Due ! to Mill --- -- - -- Wear -- ~ Joint 8 300 Severe Buckling Joint 9 -- - - - -- 350 Joint 10 -- _. Severe - - Buckling 400 Joint 11 450 Joint 12 Joint 13 ---- Impaired 500 Fingers Joint 14 Impaired Fingers / Severe - - -- Buckling 550 Joint 15 - --- Impaired _ _ - - - Fingers / Severe -- Buckling Joint 16 600 Impaired Fingers / - Severe Bucklin • • - - Joint l7 - Impaired 650 Fingers I Severe Buckling Joint 18 Impaired - -- _ - - Fingers 700 Joint 19 Impaired Fingers / -- _ Severe Buckling 750 Joint 20 i I d mpa re Fingers / -- Severe Buckling -- -- - - Joint 21 0 Impaired 8 0 Fingers 1 __ Severe Buckling --- - .-- Joint 22 - Impaired 5 Fingers 8 0 Joint 23 - - Impaired Fingers 90 0 Joint 24 I i d - -- --- mpa re Fingers - - -- Joint 25 950 Impaired - - __ Fingers / S -- - - - evere Buckling Joint 26 Im aired - -- • • Fingers / Severe _ - - Buckling Joint 27 - __ Impaired Fingers 5 10 0 Joint 28 Impaired Fingers Buckling 1100 Joint 29 Impaired Fingers --- Buckling 1150 Joint 30 Impaired Fingers Joint 31 1200 Impaired Fingers Joint 32 Impaired - Fingers 1250 Joint 33 Impaired _. _. Fingers 1300 Joint 34 _ - Impaired Fingers 1350 Joint 35 Impaired Fingers • • Joint 36 Impaired 1400 - Fingers Joint 37 Impaired Fingers 450 - -- Joint 38 Impaired Fingers -_ _ Joint 39 Impaired Fingers 1500 _ 1550 Joint 40 Joint 41 1600 Joint 42 1650 Joint 43 - - Joint 44 Top of 7" 170 Casing 0 • II C II Well: 2A-05 Field: Kuparuk ~ Company: ConocoPhillips Alaska, Inc. '~ Country: USA Minimum Deter Profile Survey Date: October 24, 2008 Tool: XR UW MFC 40 No. 213121 Tool Size: 2.75 inches Tubing I.D.: 8.765 inches Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 0.1 ' 2 4 6 8 I • 10 I . 12 14 16 - 18 - 20 - d - E 22 - e - z - za o - 26 28 30 3z 34 36 38 - 40 - 42 - Impaired Fingers • • PDS Report Overview ~ S . Body Region Analysis Well: ZA-05 Survey Date: October 24, 2008 Field: Kuparuk Tool Type: XR UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 36 ppf J-55 8.765 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body t~ metal loss body 30 20 I 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 45 pene. 1 21 14 5 1 3 loss 14 25 2 1 1 2 Damage Configuration (body ) __... . 40 30 ~ ' - 20 I 10 -- 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints dama ed total = 43 0 35 5 0 3 Damage Profile (% wall) ~ penetration body i~ meta- loss body 0 50 0 10 Bottom of Survey = 44.1 100 20 30 40 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEEP Pipe: 9.625 in 36.0 ppf J-55 Well: 2A-05 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 8.765 in Country: USA Survey Date: October 24, 2008 Joint No. Jt. Depth (Ft) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Lass `% Min. LD• (Ins.) Damage Profile Comments (%wall) 0 50 100 .1 1 () 0.06 14 2 8.67 PUP Shallow mill wear. 1 7 0 0.06 14 2 8.68 Shallow mill wear. 2 46 0.06 0.11 27 4 __ 8.71 _ _ Mill Wear. Severe Bucklin . 3 86 0 0.06 14 3 8.70 Mill Wear. Severe Bucklin . 4 124 0 0.07 17 4 8.70 Shallow mill wear. Severe Bucklin . 5 163 0 0.96 100 96 7.19 Mill Wear. Severe Buckling. - 6 02 0.31 1.24 100 88 7.48 Mill Wear. Severe Bucklin _ 7 242 0.20 0.97 100 76 8.58 Mill Wear. Severe Bucklin _ _ 8 281 0 0.10 23 13 8.68 Mill Wear. Severe Buckling. ' 9 321 0.06 0.09 21 13 _ 8.26 Mill Wear. Deposits. 10 360 0 0.27 62 22 8.58 Mill Wear. Severe Bucklin Lt. De osits. 11 400 0.07 0.08 19 5 _ _ 8.56 _ Shallow mill wear. Lt De osits. 12 438 0 0.08 19 4 7.78 Shallow mill wear. De osits. 13 478 0.04 0.10 24 3 8.01 Irrr aired Fin ers. Mill Wear. 14 517 0.()7 0.11 25 5 7.93 Irn aired Fin ers. Mill Wear. Severe Bucklin . 15 555 0.00 0.04 10 4 7.97 Irn aired Fin ers. Mill Wear. Severe Bucklin . 16 592 0.02 0.04 9 4 7.99 Im aired Fin ers. Mill Wear. Severe Bucklin . 17 632 0 0.05 11 2 7.91 Irn aired Fin ers. Mill Wear. Severe Bucklin . 18 671 0.00 0.03 7 3 7.95 Im aired Fin ers. Mill Wear. De osits. 19 710 0 0.05 11 3 7.90 Im aired Fin ers. Mill Wear. Severe Bucklin . 20 749 0.04 0.06 13 3 7.87 Im aired Fin ers. Mill Wear. Severe Bucklin . 21 789 0.03 0.05 11 4 7.84 Im aired Fin ers. Mill Wear. Severe Bucklin . 22 828 0.04 0.04 8 1 7.81 Im aired Fin ers. Mill Wear. 23 867 0.04 0.05 11 2 7.80 Im aired Fin ers. Mill Wear. 24 905 0 0.04 10 1 7.73 Im aired Fin ers. Mill Wear. 25 945 0 0.06 13 1 7.72 Im aired Fin ers. Shallow mill wear. Severe B 26 984 0 0.04 10 2 7.61 Im aired Fin ers. Mill Wear. Severe Bucklin . 27 1024 0.01 0.03 7 2 7.48 Im aired Fin ers. Mill Wear. 28 1063 0.01 0.04 10 2 7.33 Im aired Fin ers. Mill Wear. Severe Bucklin . 29 1103 0.02 0.04 10 1 7.19 Im aired Fin ers. Mill Wear. Severe Bucklin . 30 1142 0.01 0.04 10 0 7.03 Im aired Fin ers. Mill Wear. 31 1181 0.01 0.05 12 1 6.97 Im aired Fin ers. Mill Wear. 32 1221 U.O1 0.04 9 1 7.07 Im aired Fin ers. Mill Wear. 33 1261 0.00 0.05 11 1 7.24 Impaired Fingers. Mill Wear. 34 1298 0.02 0.03 7 1 7.17 _ Irr)paired Fingers. Mill Wear. 35 1338 0 0.04 9 0 7.23 ~ _ Impaired Fingers. 36 1376 0 0 0 0 _ 7.38 Impaired Fingers. 37 1416 0.04 0.03 8 1 7.32 _ _ __Impaired Fin ers. Mill Wear. 38 1454 0.07 0.03 7 1 7.93 _ Irn aired Fin ers. Mill Wear. 39 __ 1493 0.05 0.03 6 1 7.84 Impaired Fingers. Mill Wear. 40 1533 0.07 0.02 5 3 _ 8.37 _ Mill Wear. Lt. Deposits. 41 1572 O.U3 0.03 7 2 8.28 Shallow mill wear. De osits. 42 1612 U.05 0.03 7 2 8.39 Mill Wear. l.t. De osits. 43 1651 0.03 0.01 3 4 8.54 Mill Wear. Lt De osits. 44 1691 0.O 0.01 3 4 8.59 Mill Wear. LC De osits. 44.1 1694 _t)_ 0 U (1 N/A Top of 7" Production Casn~_ _ Penetration Body Metal Loss Body Page 1 PDS Report Cross Sections Well: 2A-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 9.625 ins 36 ppf I-55 Survey Date: October 24, 2008 Tool Type: XR UW MFC 40 No. 213121 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint 6 at depth 219.193 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 80 Tool deviation = 4 ° Finger 32 Penetration = 1.244 ins Mill Wear 1.24 ins = 100% Wall Penetration HIGH SIDE = UP • • Cross Sections page 1 PDS Report Cross Sections ~ -- ~- Well: 2A-05 Survey Date: October 24, 2008 Field: Kuparuk Tool Type: XR UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Analyst M. Lawrence Cross Section for Joint 7 at depth 254.263 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 55 Tool deviation = 2 ° Finger 17 Penetration = 0.97 ins Mill Wear 0.97 ins = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 PDS Report Cross Sections ~ -- ~- Well; 2A-05 Survey Date: October 24, 2008 Field: Kuparuk Tool Type: XR UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: M. Lawrence Cross Section for Joint 5 at depth 194.283 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 17 Tool deviation = 1 ° Finger 20 Projection =-1.580 uis Deformation Due to Buckling and Apparent Mill Debris Minimum I.D. = 7.19 ins HIGH SIDE = UP • • Cross Sections page 3 ~, ~~~ KUP ~ 2A-05 COfIOCOP~'II~~I~ JS Iwe11 Attributes a'~.I~..., I II WMboreMWWI dd Name WeR 9tams 1 ptttal oral Depth ptK 501032003000 KUPARUK RIVER UNR PROD 57.02 7,200.00 9,185.0 ••• Cotrmlerx SSSV: Nza (ppln( Date Amatatlat 6M Defe ~-" KB•Gfd (R) Rlg Rgease Dle 50 5!16/1984 220 7/7/2008 Last WO: 40 el o aoe 44~:~s:w . - -- _-_ MtOtsdon Depth IRKS) eM Otte Amolatlon Btd e Last Tag: 8,840.0 3/412004 Rev Retimn: SHOW WRP @ 8591' 91?/2008 Casin Strip s t Casing l><scdp8on OD pry ID(kll Top pD(Bi SN epth RtKdl Set Depm (TVD) (RK8) Nsltq Graee Top Mead _ CONDUCTOR 18 15.080 0.0 104.0 104.0 62.50 940 rul»n9Nenger. 34 SURFACE 95/8 8.765 0.0 3,209.0 2,618.3 36.00 Jb5 ---------- --~ : - - -- --- PRODUCTION 7 6.151 0.0 9.060.0 6,151.9 26.00 Jb5 Tubin Strip s 7udn Descdptlon t>D (kt) ID (k4 Top (RK6) sq (RIBI Set Depth lTwllRlm Wt pbsrtry Crada T Trsad KILL STRING 2 7/8 2.441 _ 0.0 3,046.6 2,517.6 6.40 L-80 Hydril 511 TUBING-Original 31/2 2.992 8,536.0 8,791.0 5,970.6 9.30 J-5 8 DEUE ABM coNDUCroR. ,~, Other In Hole All JawvNr : Tubi Run 8 Retrievable, Fish, etc. Top (ftl(B) ~ lksctipdon Comment Rtn Date ID 6M r 3,483.0 i I Revievable Bridge Plug Baker 3" IBP w! 1.75" external fuhnedc. 300 Ibs sand on top of Plug 7/16/2008 8,555.0 PBR Baker 6128/1964 3.000 8, 8.0 Baker' HL' 8/1 3.000 SURFACE, 709 J 8,591.0 WRP 2.69° WRP 5/292008 0.000 . 8,607.0 PRODUCTION MMH/FMHO/1/CV/BROKEW// Cmment STA 1 72/7999 2.859 Retnevage 8,675.0 PRODUCTI N MMHIFMHO/1/CV //German! STA2 3/5/2004 2.859 ena9e Plug. 483 3 8.781.0 PKR Baker'FB•1' 628/7984 4.000 . 8,789.0 NIP Carttco'D' Nipple NO Go 6rza/1984 2.750 8,790.0 SOS BekN 628/1984 2.992 8,797.0 TTL ELMD @ 8761' ON OTIS LOG 1 2517984 612 1964 2.992 8,907.0 Fish 1"GLV FELL TO RATHOLE 6211999 PRR. e.sss Perforations PxR.e,s6e ~ - ~ _; Toplm®1 Bmtp~l Top (TVDI IRlml Btm (TVD) (RNA Type Zane Dents Istwt_ Date comment 8,692.0 8,730.0 6,904 4 6,929.8 APERF C4, UNIT B, 2A-05 12.0 62811984 120 deg ph; 5.5" Csg Gun 8,762.0 8,784.0 5,951.2 5.965.9 APERF A4, 2A-05 4.0 628/7984 90 deg. ph; 4' Csg Gun VhtP, 9,591 8,764.0 8,776.0 5,952.5 5,960.5 REP F A4, ZA-05 4.0 6/8/1988 Zero deg. phasing; Gearhard EJ II 8,796.0 8,655.0 5,973.9 6,013.4 RPERF A-3, 2A-05 4.0 628/1984 90 deg. ph; 4" Csg Gun 8.798.0 8,834.0 5,975.2 5,999.2 REPERF A-3, 2A-05 4.0 6!8/1988 Zero deg. phasing; Gearhard EJ II PROOUCrroN. Notes: Gene ral 8 SaR B.BOT B1d Dqe Annotatbn 6/3/1999 NOTE: We9 has serious scale poblerrts. 122201M NOTE ORKSCREWED TUBING STARTING ~i18659'WLM RtODUCTION 8!312004 NOTE: WAIVERED WELL IAx OA COMMUNICATION . e.sTS 5/12008 NOTE CORKSCREWED TBG FROM 8535' 92/2008 NOTE: SCMT 7/192008 SHOWS TOP OF CEMENT @ 1970' APERF, e,B82-6,730 REPERF, 8,764-8,778 ~ _ APERF, 8.762-8.784 -~'~~ PRR, 8,i81 EPERF, 8,19&8.834 RPERF, 8,796A,855 FisE. 8 901- PRODUCTION. 8.060 1~ TD, 9,165 ~ I I I i~ , I i l I ~'i ', • _ ALL ~ _ ~1~~4/US/CAL a=~._. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 r ~ x ~._ _ ~' ~~ ~~ L RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey U"t C tb~c - (~~" 130 West International Airport Road~,/~ ~ ZU ~~~~ Suite C Anchorage, AK 99518 Fax: (907) 245,8952 ~~ br~- 1 J Caliper Report 2] 19-0ct-08 2A-05 Signed Print Name: ~~r~~~~a _ ~~a~ 1 Report/ EDE 50-103-20030-00 Date : ~ _ . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~d~aca~i~flrSge~~~rs~~rj~loq.~~rrfi: WEBSITE:uw~rw,t~;~~sorylr~cl.c~r~ c'~ C:\Documenls and Settmgs\Ownet\Desktop\Transmit_BP.doc i~ Memory Mu1~i-Finer Calmer Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: ZA-05 Log Date: October 19, 2008 Field: Kuparuk Log Nix.: T2~4' ~tate~: Atasira Run No.: 4 API No.: 50-103-20030-00 Pipet Desc.: 9.625" 36 Ib. J~5 Top Log Intel: Surface 1~re1 lJse: Star-fae~ Casing- Bot Lag i~ti: 1;581 ft, (~} Inspection Type : Surface Casing Deformation Inspection ccMs This caliper data is tied into the top of the 9.625" Surface Casing at 0'. This-log vas-run=to-~ssess~~e cor~di~on oaf tlae 9-~25" -su~#ace~-~-de#er~aine point~s~# with the conductor pipe and to locate intervals of deformed surface casing. The caliper recordings indicate deformation due to severe buckling in joints 2 to 10, 14 to 17, 19 to 21, 25, 26, 28 and 29.3-D log plots of the r e-c~nter~ed~~d o#-~tn#er- calper recordings taf -en5r~#og inter~rai ~e tneluded in th~ f~or#: ' Deformation due to severe buckling restricts the I.D. to 5.85" at 189'. Heavy, ring like deposits are recorded at ~40' intervals throughout the surface casing logged. Additional heavy deposits are recorded from 1,410' to 1,681'. No significant v/all penetrations or areas of cross-sectional wall loss are recorded-.throughout_the surface casing logged. This fs the fourth-time a PD5 caliper has taeen run in this. wetland the fifst #ime gre 9:625" surface casing has been logged. A comparison of this log and. the caliper log dated July 19, 2008 suggests the heavy, ring-like deposits recorded at ~40' intervals are associated with the 7" tubing collar locations prior to removal. Throughout various portions of this log, deposits obstructed individual fingers, identifiable by a span of unchanging finger recordings. The reported diameters in these intervals are likely smaller than the actual ~mrot#hta p~° v ~;~,~~~~~~ ~~`J1' ~ ~ X00 MAXIMUM RECORDED WALL PENETRATIONS 1 X14 cignifir~nt Il nc~nptra.~,.tit~nc (> 7°~0~ ~r~_I~~4rd~d #k)r~ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No~igr~frcan# ~reas.~# cr-oss~~ec#ior~l 11.1oss-{> 1~°y~,.~e: record, MAXIMUM RECORDED ID RESTRICTIONS Deposits Minimum I.D. = 5.84" Jt. 37 @ 1,413 Ft. (MD) Deformation due to Buckling Minimum LD. = 5.85" Jt. 5 G 189 Ft. (MD) ' ~eposi~ ~~, I~LI. = 6.2<1" ~.. 3.5 ~ 1, EL, (1~} Deposits Minimum I.D. = 6.27" Jt. 33 @ 1,297 Ft. (MD) Field Engineer. Wm. McCrossan Analyst: M. Lawrence Witness: R. Overstreet I ~ ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or {888) 565-9085 Fax: (2S1) 565-1369 E-mail: PDS~amemoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 l7S-~'- ~b~l-~'~- 1029 ' • ' - PDS Multifin er Cali er 3D Lo Plot g P g ~~_. .~ ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-05 Date : October 19, 2008 Description : Detail of Caliper Recordings Across Severely Buckled 9-5/8"Surface Casing ' 1 500 - __ _- `' i ' 0 1 Pu Jt. 0.1 Joint 1 - - -- ~ ~ - --- _ I 50 Joint 2 - Severe ' Buckling - ,~-- _ -__ ~- ' Joint 3 100 Severe Buckling - --- - -- -- ~ - - Joint 4 _ _ _ Severe _ - Buckling 150 ,;- Joint 5 1 Severe - _ - ,.. '~ ~~~--'--- ~ - - -- - .. ' 200 ` .. ,~ __ w,,, Joint 6 "~' Severe - ~::.; I ' Buckling - ::;.. - ..~: 1 • Joint 7 Severe Buckting - --- - Joint 8 Severe Buckling 300 Joint 9 Severe Buckling - - - _ ..- 350 Joint 10 Severe Buckling __ __ - - - - _ - - --- 400 Joint 11 450 Joint 12 Joint 13 50 0 Joint 14 Severe Buckling -- - - - Joint 15 Severe Buckling 550 _ _ Joint 16 Severe Buskluig 600 - - - • • Joint i7 Severe Buckling 650 Joint 18 700 Joint 19 Severe Buckling --- _. _ Joint 20 Severe 750 _ _ .. --- - _ _ Buckling _ Joint 21 Severe 800 Buckling - - ..__ . __ _ Joint 22 ___ 850 Joint 23 - - - _- Joint 24 900 Joint 25 Severe Buckling 950 _ ~ Joint 26 r • • Buckling Joint 27 - 1050 Joint 28 Buckling -_ . - Joint 29 Buckling 1100 Joint 30 1150 --- -- Joint 37 -- - - 1200 :~ Joint 32 1250 Joint 33 Temporarily Impaired Fingers --- Joint 34 1300 Joint 35 1350 a ~ ~ f I • Joint 36 - _-- 1400 Joint 37 1450 - - Joint 38 Temporarily Impaired Fingers _ _ - _ Joint 39 Temporarily 1500 Impaired Fingers _. _ - Joint 40 Temporarily _ Impaired Fingers 1550 J i t 41 o n Temporarily _ -- _ - Impaired Fingers 1$00 _ - Joint 42 Temporarily Impaired Fingers - - Joint 43 Temporarily Impaired Fingers 1650 _ - -- ---- i +. ~.~.. . ~ _ ~~ ! ' ~ ~ ~ ~~~ ~, ~ ~: ~~ r 1 F~ ~ ~ ~~~~. a II' ~~. _. ~~ ~~' <, • ~ PDS Multifinger Caliper 3D Log Plot ~. ~, Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-05 Date : October 19, 2008 Description : Detail of Off-Center Caliper Recordings Across Severely Buckled 9-5/8" Surface Casing • • Joint 7 Severe _- - --- Buckling _ _ - - ~ !'~ - r4 J Joint 8 300 , r '~ ~ :. Severe Buckling _- __ ~ E. " ._ 'a''- Joint 9 Severe - - - _ _ _ Buckling . ~,. _ 350 ~ , _, t ~.~ ~ _ -- - - _ - - - Joint 10 Severe _ -- - - - < Buckling 400 ` °° - a'; Joint 11 .~,. 450 Joint 12 -- ,z Joint 13 500 r Joint 14 - -- - Severe ,;; ~ - ~' Buckling - _ ~ , ,. :.c 550 '` Joint 15 ~'" `" ~ ~ Severe Buckling 1 - r 600 ~~f Joint 16 Severe -- -- - _ _- - -- __ ~ ; 6uclcling - , • Jant 17 Severe Buckling 650 Joint 18 700 Joint 19 Severe Buckling - - 750 Joint 20 Severe Buckling _ _ _ 8 Joint 21 Severe 00 Buckling Joint 22 850 Joint 23 -- -- 900 Joint 24 0 Joint 25 Severe Buckling 95 - - --_ Joint 26 J 1 II __ • ~ i~ • Joint 36 -- _ _---- 1400 Joint 37 _ - - - 1450 - _ - _ - - _.. Joint 38 Temporarily Impaired Fingers Joint 39 Temporarily 1500 Impaired Fingers - _ Joint 40 Temporarily - -- Impaired Fingers 1550 Joint 41 Temporarily Impaired Fingers -- - --- - 1600 Joint 42 Temporarily - _ Impaired Fingers - -- _ Joint 43 Temporarily Impaired Fingers 1650 - -- aR~~ r ,~ M~~.~ ~-~.: ~' _ a ~= +, ~ -- ~i ., ?i~w ~~ .; _ w ~ ` ~ ~ ~ y ~ ~ o w ~ ~° 9 ~ ~,, m~ i~ . h ~ t~ • • ~-~~ Minimum Diameter Profile N~'ell: '~-OS Survey-Date: October 19, ~'OOFt Field: Kuparuk -fool: Xh UW MFC 40 Nv. _'1 Lt Con~pam•: CviroroPhdhps -Alaska, hx. Tool tilze: '.75 in~.hes Country: USA Tubm~ LD.: Y,JG i uxhes Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 01 ' ^ ^ a , ~ ^-_ 8 10 f2 IJ ^ 16 ' I 18 , ~ =U L - Z .~ .J ~~ ~8 3U I I . 3. I 3a I I I I , 3b za au a_ • • PDS Report Overview -~. S . Body Region Analysis b'Vell: 2A-05 Survey Date: October 19, 2008 Field: Kuparnk fool type: Xh UW ,~1FC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. -fool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: ,ti. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.fs25 ins 43 ppt )-55 8.765 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) _ penPtriltlOn body nletal TOSS 60(ly 50 4f1 30 20 0 - 1 ~ 0 0 to 1 to l0 t€> 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal secl (total = 44 gene loss . 0 44 0 0 0 0 13 31 0 0 0 0 Damage Configuration (body ) 0 1 ) t isolated generll hne nng hole / pons pimng corrosion corrosion corrosion dale hole Number of ~oints clanri ed (total = 0) 0 0 0 0 0 Damage Profile (% wall) ~ penetration hotly 1~ meGil loss body 0 50 0 1(1 20 30 40 Bottom of Survey = 43 100 Analysis Overview page 2 PDS~EPORT JOINT TABULATION SAEEf Pipe: 9.625 in 43.0 ppf J-55 Well: 2A-05 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: ConoeoPhillips Alaska, It~c. Nominal I.D.: 8.765 in Country: USA Survey Date: October 19, 2008 Joint No. It. Depth (Ft.) 11~n. lll,tit~t !I11~.~ Pen. Bocly II+K.J Pen. % ,~tet~l lu,ti .~~ rain. LD• ll4K.J Comments Damage Profile (%wall) Q SO 100 .1 1 it 0.02 8.64 PUP Lt. Deposits. 1 G u 0.02 (~ 8.58 Lt. De posits. 2 45 i ~ 0.03 (; ; 8.48 Severe buckli Lt. De posits. 3 84 ~~ 0.03 h ; 8.53 Severe bucklin Lt De x~sits. 4 1 "?3 ~~ 0.02 (~ ~ 8.(i3 Severe bucklin Lt. De x>sits. 5 162 1~ 0.02 5 4 5.85 Severe bucklin De posits. 6 201 ~ ~ 0.02 ~ (i.95 Severe bucklin De x>sits. 7 240 U 0.03 (, _' 7.64 Severe bucklin De xxits. 8 280 it 0.03 6 ; 7.84 Severe bucklin . Dex~sits. 9 319 ~~ 0.02 i _' 752 Severe bucklin . Dex~sits. 10 361 (1 0.03 ~ ; 7.52 Severe bucklin Deposits. 11 398 ~~ 0.02 -> 8?9 De posits. 12 436 i ~ 0.02 5 8.67 13 47 6 r 1 0.02 5 ..' 8.54 Lt. De >osits. 14 516 ~) 0.02 i _' 8.51 Severe bucklin Lt De posits. 15 554 O 0.03 (~ ; 8.21 Severe bucklin De x~sits. 16 590 U 0.03 (~ ; 8.(i(i Severe bucklin. 1-t. 17elx~sits. __, -- 17 _ (i30 ll 0.(13 8.(i7 Severe bucklin 18 669 a 0.03 (~ 4 8.58 Lt De x~sits. 19 708 U (lA3 (, 7.84 Severe bucklin De posits. 2fl 747 i ~ 0.03 (~ 7.67 Severe bucklir De posits. 21 787 i ~ 0.02 i ; 7.87 Severe bucklin De )osits. 22 825 i 1 0.02 5 8.2(i De x~sits. 23 864 i) 0.02 4 4 8.60 _Lt. [>e-~osits. 24 _ 902 a 0.02 4 4 ._. 7.78 . De x~sits. 25 942 U 0.(12 ; 3 7.29 Severe bucklin De x~sits. 26 982 n 0.02 4 1 7.14 Severe bucklin De )osits. 27 1021 a 0.01 ; u 8.38 C)e )OSrtS. 28 1060 n 0.01 ~ I 7.62 Bucklin De posits. 29 1100 ~~ 0.01 ; I 7.27 Bucklin Dex>sits. 30 1139 ~~ 0.01 tt 8.40 Lt De>osits. 31 1178 n 0.02 4 7.(i4 De posits. 32 1218 ~~ 0.01 G90 Ue x~sits. 33 1261 ~~ 0.02 4 ~~ 6.27 Ue )osits. 34 1298 t) 0.01 2 n 8.59 Lt. D x~sits. 35 1334 U 0.111 i I 6.21 De x~sits. 36 1373 ~~ 0.01 U 6.42 De posits. ~7 1 4 ~) i! OA' 4 ~4 L)~posits. _ ..__ 38 . -_ - 1450 U _ 0.01 __ =_,_ ; Il 6.89 =-- De x~sits. 39 1490 i> 0.01 ; 1 7.30 De x~sits. 40 1529 I ~ 0.02 4 7.15 De >osits. 41 15F~9 a 0.02 4 ~) 7.12 C)e x~sits. 42 1(i07 I) 0.02 4 _' 6.52 De )osits. 43 1651 tl 0.01 ? _' S.J4 De x~sits. _ Penetration Body Metal Loss Body Page 1 PDS Report Cross Sections Well: 2 A•05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 9.625 ins 43 ppf J•55 Survey Date: October 19, 2008 lool type: XR 1.1W MFC 40 No. 213121 Tool Size: 2.75 No. of Fingers; 40 Analyst: M. Lawrence Cross Section for Joint 5 at depth 189.19 ft focil speed = 43 Nominal ID = 8.765 Remaining wall area = 86 Todl deviation = 3 ° Finger 36 Projection = -3.01 1 Ins Severe Buckling and Deposits Minimum LU. = 5.$5 ins HIC;H SIDE = UP • • Cross Sections page 1 PDS Report Cross Sections Well: 2A-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing. 9.625 ins 43 ppf J-55 Survey Date: (:)ctober 19, 20178 lool Ivpe: XR lJW MFC 40 No. 213121 lool Sve: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint 6 at depth 225.17 ft fool speed = 43 Nominal ID = 8.765 Nominal (:)D = 9.625 Remaining wall area = 100 Tool deviation = 4 ° Finger 23 Projection = •1.084 ins Severe Buckling and Deposits Mininuun LD. = 6.95 ins HIGH SIDE = UP i • Cross Sections page 2 ~ ~P _ 2A-05 C'nnnrnPhillir~c ~ / ~ I~ Attributes -~ ~`~~ ~`"`~° ~~~ Al;~ska, .. `" ' i I~ ~ Weflbore API/UWI 501032003000 Fkld Name KUPARUK RIVER UNIT Well Status Ineflnatlon (°) PROD 57.02 1ND (ttK6) 7.200.00 T«al Depth (ftKB) 9.185.0 ... - Comment SSSV: H2S (ppm) 220 Date 7/1/2008 Annotation Last WO: End Date K61'ird (ft) 40.50 Rlg Release Date 5/16!1984 con srznoos a 4e o s Pnn Sc emahc -Actual ---- --- Annotation Depth (ttK6) End Date Annotation End Date Last Tag: 8.840.0 3/4!2004 Rev Reason: SHOW WRP @8591' 9/2/2008 Casin Strin s _ Casing Description OD (In) ID (In) Top (ttK6) Set Depth (ftKB) Set Depth {TVD) (ftKB) Wt (Ibsift) Grade Top Thread _ _ _ CONDUCTOR 16 15.060 0.0 104.0 104.0 6250 H-40 Tubing Hanger. 34 _ SURFACE 95/8 8.765 0.0 3.209.0 2618.3 36.00 J-55 - - - - - - - - - - - - - - - PRODUCTION 7 6.151 0.0 9.060.0 6.151.9 26.00 J-55 Tubin Strin s Tubing Description OD (M) ID (In) Top (ttK6) Set Depth IttK6] Set Depth (TVD) (ttK6) Wt (Ibsftt] Grade Top Thread KILL STRING 27/8 2441 0.0 3.045.6 2517.6 6.40 L-80 Hydril511 TUBING -Original 3 1/2 2.992 8,536.0 8.791.0 L 5.970.6 9.30 J-55 8RD EUE ABM CONDUCTOi4 _. Other In Hole All Jewel : Tubin Run & Retrievable, Fish, etc. Top (ftKB) Description Comment Run Date ID (in) 3.483.0 Retrievable Bridge Plug Baker 3" IBP w/ 1.75" external fishneck. 3001bs sand on top of Plug 7!16/2008 8,555.0 PBR Baker 6/2811984 3.000 8.568.0 PKR Baker'FHL' 6/28/1984 3.000 SURFACE _ 3109 8.591.0 WRP 2.69" WRP 5/29/2008 0.000 8.607.0 PRODUCTION MMH/FMHO/1/CV/BROKEN///Comment: STA 1 7/2/1999 2859 Relnevabk -- - 8.675.0 PRODUCTION MMH/FMHOIi/CV/BK1// Comment STA 2 3/5/2004 2859 Bridge slug. 3,483 8.781.0 PKR Baker'FB-1' 6/28/1984 4.000 8.789.0 NIP Camco'D' Nipple NO GO 6/28/1984 2.750 8.790.0 SOS Baker 6/28/1984 2992 8.791.0 TTL ELMD @ 8761' ON OTIS LOG 11/25!1984 6/28/1984 2992 8.907.0 Fish 1" GLV FELLTO RATHOLE 6/2/1999 PBR, 8.555 Perforations sn« r. PKR. 8.568 t _ ~ I Top (ftKB) Btm (ttK6) Top (TVD) (ttK6) Btm (TVD) (ftKB] Type Zone Dens (shot... Date Comment 8.692.0 8.730.0 5,904.4 5.929.8 APERF C-4, UNIT B, 2A-05 120 6/28/1984 120 deg ph; 5.5" Csg Gun 8.762.0 8.784.0 5.951.2 5.965.9 APERF A-4. 2A-05 4.0 6/28/1984 90 deg. ph; 4" Csg Gun WRP asst 8,764.0 8.776.0 5,952.5 5,960.5 REPERF A-4, 2A-05 4.0 6(8/1988 Zero deg. phasing; Gearhard EJ II 8.796.0 8.855.0 5.973.9 6.013.4 RPERF A-3. 2A-05 4.0 6/28!1984 90 deg. ph: 4" Csg Gun ~I ~ 8.798.0 8.834.0 5.975.2 5.999.2 REPERF A-3. 2A-OS 4.0 6/8/1988 Zero deg. phasing: Gearhard EJ II I PROOUCnoH. Notes: General 8 Safe '. 8.607 End Date Ann«atlon 6!3/1999 NOTE: Well has serious scale problems. 1/22/2004 NOTE: CORKSCREWED TUBING STARTING @8659' WLM PRODUCnoN 8f3112004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION . 8.675 5!1/2008 NOTE: CORKSCREWED TBG FROM 8535' APERF. _ 8,692-8,730 -~ REPERF. 8.764-8.776 ~_ _ ~...-. APERF. 8,762-8.784 - PKR. 8.781 ~ - _,s - - r ~ 9/2/2008 NOTE: SCMT 7/19/2008 SHOWS TOP OF CEMENT @ 1970' • • SARAH PALIN, GOVERNOR ~~"~~~--~~ OaL L>•1`L ~ 333 W. 7th AVENUE, SUITE 100 C01~51' RVA'rIO1~T CO1rII~IIS5IOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Ennis Wells Group Engineer ConocoPhillips Alaska Inc. PO Box 100360 ~ ~ Anchorage, AK 99510 ~ (~ (.~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-05 Sundry Number: 308-314 ~~~,NiUfQ SEP ~ 2008 Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may. file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Daniel T. Seamount, Jr. Chair CC `7~~1 DATED this J day of September, 2008 Encl. 'O • STATE OF ALASKA • ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~y S EP ~ ~ 20 Vr APPLICATION FOR SUNDRY APPROVka Oil & Gas Cons. Commission 20 AAC 25.280 8nr.~1nC80@ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^~ - Repair well Q Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development ^ Exploratory ^ 184-067 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20030-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO Q 2A-05 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25570 ~ RKB 130' - Kuparuk River Field /Kuparuk Oil Pool - 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth nnD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9185' ~ 6236' 3485' 2786' 3485', 8591' 8907' Casing Length Size MD ND Burst Collapse CONDUCTOR 104' 16" 104' 104' SURFACE 3209' 9-5/8" 3209' 2619' PRODUCTION 9060' 7" 9060' 6152' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8692'-8730', 8762'-8784', 8796'-8855' 5904'-5930', 5951'-5966', 5974'-6013' 2-7/8" kill string H dril 511 3019' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER'FHL' ; BAKER'FB-1' pkr= 8568' ; 8781' no SSSV no SSSV 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ^~ BOP Sketch ^ Exploratory ^ Development ~ ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat September 15, 2008 Oil 0 ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the egoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Name Title: Wells Group Enginee Signature Phone 265-6845 Date ~ ~ 0 Commission Use Onl Sundry Number: Conditions of approval: otify Commission so that a representative may witness grity Location Clearance ^ Plug Integrity ^ BOP Test Mec h nica l Inte T a est ^ l ( ( ~ ~ ` _ ` Other: ~.~- '~ P'f'CSSJt'2- ~ES~ "CGS \S `S"~c(~~~ ~o~ MvS"'~~~c C,.~~~@ t~ ~~ ~' ~~~ ~f~~N1 I Subsequent Form Required: , `~~\ APPROVED BY ~ J~ Approved by: COMMISSIONER THE COMMISSION Date: ~ / / Form 10~fsed 06 6 Submit i~plicate l~ ~ ~ ~ i~ S ~F~> SEr 4 ~ 2008 - ,~°<<<~ p' ~'~~ Rig Workover Sundry Procedure. Well 2A-05 Kuparuk Producer Replace damaged csg, upsize tbg & install GLM's PTD# 184-067 1. Verify sundry approval has been received. 2. MIRU Nordic #3. Verify well is dead. Paint line on tree, tbg head adapter and tbg head. Take photo of tree position for reference at end of workover. 3. ND tree. Install blanking plug in hanger lift threads. NU 11" BOP. Function tesf BOP. PT BOP rams to 250/2500 psi and annular to 250/2500 psi. (MASP 2092 psi using 4/13/08 SBHP & 0.1 psi/ft gradient) Pull blanking plug & BPV. (Note: 24 hr advance notification to AOGCC required prior to testing BOPE.) 4. PT csg & IBP to 2500. psi. Unland tbg hanger. POOH laying down 2.875" kill string. Note: No equipment shall leave location until surveyed for NORM. 5. RIH w/ 3.625" .multi-string cutter dressed for 7" casing on workstring. Cut 7" csg mid-joint @ 1695' MD (TOC on 7-19-08 SCMT @ 1970' MD). POOH. Est -circ w/ seawater & pump until clean returns. 6. NDBOP & tbg head. Spear 7" casing w/ 5.75" Itco spear. POOH. sideways w/ 7" csg. 7. RU slickline. Roundtrip PDS 9.625" csg caliper & GR/CCL memory tools to 7" stub. RD slickline 8. RIH w/ 7" dress-off mill assembly to swallow 6' of csg stub as follows: a) Guide shoe b) 10' washpipe extension containi~~g 7"' csg OD dress-off mill c) Boot basket d) Bumper jar e) Oil jars f) 6 DC's Dress csg`stub. Circ clean. POOH. 9. RIH w/ 7" packoff overshot, 10' csg pup, HES Type H ES cementer w/ six shear pins (3300 psi to open w/o opening plug) on new 7" 26# L-80 BTC Mod csg w/ one centralizer per joint. Bakerlock all connections below `ES' cementer. Engage stub & overpull 50M#. PT csg to 2500 psi. Land 7" csg on slips w/ 50M# tension. Install Vetco csg packoffs. Drop `ES' opening plug in 7" csg. NU HES cement head w/ `ES' closing plug loaded. 10. RU SLB cementers. Pressure csg to 1000 psi to open `ES' cementer. Est circ w/ 100 bbls hot seawater @ 5 BPM. Pump 60 bbls (20% excess) 15.7 ppg ArcticSet1 cement w/ 2 hr pump time @ 50 deg F. Launch closing plug and displace w/ 65 bbls hot seawater until bump to close `ES'. After good cmt returns to surface are achieved, close OA valve to squeeze cement into 9-5/8" csg leak @ -210' MD. After plug bumps & closes `ES', PT 1500 psi. Bleed off & verify no flow. ND HES cement head. WOC 4 hours to allow it to achieve 500 psi compressive strength. Jim Ennis Page 1 8/29/2008 .Rig Workover Sundry Procedure. Well 2A-05 Kuparuk Producer Replace damaged csg, upsize tbg & install GLM's PTD# 184-067 11. NU FMC tbg head & BOP stack. PT csg, tbg head & BOP body 2500 psi. RIH w/ 6.125" mill tooth bit & DC's on 3.5" workstring to `ES' cementer. Drill up HES plugs & chase to top of sand @ 3450' MD. PT csg to 2500 psi.. Dry drill debris on sand to crush. POOH. 12. RIH w/ 10' wash shoe & inside junk baskets on workstring. Tag sand & reverse circ down to IBP. Circ hole over to 9.6 ppg brine. POOH. 13. RIH w/ IBP, retrieving head on workstring to IBP. Engage IBP & release. POOH laying down. workstring &IBP. 14. RIH w/ following on workstring: a) 3.625" ID Baker Poorboy overshot w/handling sub b) 2.813" `DS' nipple w/ RHC plug installed w/ handling subs c) FHL pkr (pinned 60M# shear) w/ handling sub below d) PBR (pinned 40M# shear) w/ handling sub above on Locate cut tbg stub @ 8536' MD and spot CI brine (1 °I° by volume -Baker Petrofite CRW-132) between packers and in well below 6000' MD. Engage tbg stub and stack 10M# over on it. Pic:,k up to string weight. Drop ball & rod. Pressure tbg up to 2500 psi and set FHL Shear PBR. POOH w/ workstring laying down. 15. Single in w/ 4.5" completion as follows: a) PBR seal assembly w/ handling ;ub above b) 1 joint 3-1/2", 9.3#, L-80, EUE 8RD Mod tubing c) 3-1/2" EUE 8RD Mod x 4.5" IBT Mod xover d) 3.813" `DB' nipple w/ handling subs e) New 4.5", 12.6#, L-80, IBT Mod tubing &KBG-2 GLM's per design below • Torque for IBT tubing is determined by averaging the make up torque required for the first 15 joints. Proper makeup occurs when the btm of the pin makeup mark is flush with the top of the collar. GLM Type MD TVD Valve 1 KBG-2 2781 2350 DV 2 KBG-2 4690 3500 DV 3 KBG-2 6184 4400 1500 psi SOV (csg to tbg) 4 KBG-2 7429 5150 DV 5 KBG-2 8485 5786 DV f) 3.875" ` DB' nipple @ 500' (3. 5" tbg above must drift 3.91") Jim Ennis Page 2 8/29/2008 Rig Workover Sundry Procedure Well 2A-05 Kuparuk Producer Replace damaged csg, upsize tbg & install GLM's PTD# 184-067 16. Space-out. PBR 2' off btm and land tbg hanger with a full joint immediately below. RILDS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 2500 psi for 15 minutes. Bleed.. off tubing pressure to 1750 psi. Holding the tubing pressure at 1750 psi, PT IA to 2500 psi for 30 minutes. Bleed off lA & then tubing pressure. Pressure IA to 2000 psi rapidly to shear the SOV. Install TWC. NDBOP. NUWH. Test tree and packoffs to 5000 psi. Pul! TWC. Freeze protect well by pumping 75 bbls diesel into IA & equalize across tree. Install BPV. RDMO. Turn well over to Production via Handover Form. Post Rig Work 1. RU slickline. 2. .Replace shear valve with dummy. PT tbg 2500 psi. 3. Retrieve ball/rod & RHC plug. Retrieve WRP. 4. Install GL design. 5. RD slickline. Jim Ennis Page 3 8/29/2008 ConocoPhittips ~~ Alasi::~, ,:. ~> Tuhirg Hanger, 34 CONDUCTOR, ,04 SURFACE, _. ~._ --__ 3.209 Retrie~eWe Bridge Rug.- ; 3.683 PBR, 8,555 PKR,8,566- WRP. 8,691 - PRODUCTION, 8,60]. --- PRODUCTION, 8,675 RPERF, 8,692$730 REPERF, 6,7644.176 APER~ 8.]624.]84 PKR, 8,761 REPERF, 8.]984,836 RPERF, 8.7964,855 Fish. 6.907-- - PRODUCTION, 9,060 \ TD. 9.185 KUP Name ARUK RIVER UNIT 2A-05 Tubing Strings _ _ S th ~ _ - - ~ 2~ Tubing Desulption ~ (I) (i) I n ID To ftKB p ( ) (ftKB~ Sat Depth (ND) (NKB) Wt (WS/fl) Grade Top Threatl I i KILL STRING j 2 7/i 2.441' 0.0 3,045.6. 2,517.6 6.40 L40 ~ Hydril 511 TUBING-Original 312 2.992 8,536.0 - 8,791.0 5,970.6 9.30 J-55 SRD EUE ABM Other In Hole l Jev~ell :Tub n Run 8 Retrievable, Fish etc. Top (ftKB) Des[riptio~ _ _ Comment Run Date ID (in)_ 3,483.0 RetrievaW~ Baker 3" IBP wl 1.75" external fishneck. 300 Ibs sand on top of Plug 7/16/2008 Britlge Plug 8,555.0 PBR Laker 6/28/1984 3.000 8,568.0 PKR Baker'FHC ,62811984 3.000 8,591.0 WRP ~ 2.69" WRP 5/29/2008 I 0.000 - -- 8,607.0 : PRODUCTION ~ __. - MMH/FMHO/1/CV/BROKEN!// Comment: STA 1 7/2/1999 ____ 2.859 8,675.0 PRODUCTION MMH/FMHO/1/CV/BK///Comment: STA2 3/52004 2.859 8,781.0 PKR i Baker'FB-1' 628/1984 4.000 8,789.0 ,NIP I Camco'O'Nipple NO GO 628/1984 2.750 I - 8,790.OI,SOS Baker 628/1984 ~ 2.992 8.791.0 ~ 1 t L ' ELMD @ 8761' ON OTIS LOG 11/25/1984 6/2&1984 2.992 890 LOIIFish __ r 1"GLV FELL TO RATHOLE __ _ _ _.-7r ~.- _ 6/2/1999 .._ _ _._ Perforations ~ ~ __jh., ` Shot ~ Tep (TYD) Btm (ND) ~ Dens Top (ftKB) Btm (fl KB) (ftKB) (ftKB) Type Zone (sh L.. Dale Comment 8,692.0 8,730.0 I 5,904A 5,929.8 RPERF C-0, UNIT 8, 2A-OS 12.0 628/1984 120 deg ph; 5.5" Csg Gun 8,762.0 8,784. i_ f,95/.2 5,965.9 RPERF A4, 2A-OS 4.0 6128!1984' 90 deg. ph; 4" Csg Gun 8,764.0 8,776.0 5,952.5 5,960.5 REPERF A-0, 2A-OS 4.0 6/8/1988 Zero deg. phasing; Gearhard EJ II 8,796.0 8,855.0 5,973-9 6 013.4 RPERF A-3, 2A-OS 4.0 6/2811984 90 deg. ph; 4" Csg Gun - 8,798.0 8 834.0 5,975.2 5,999.2 ' REPERF __ A-3, 2A-OS 4.0 6/8/1988 Zero deg. phasing; Gearhard EJ II -_ Notes: Genera} 8r'S~ety End Date Annotation . ~ ~. 6/3/1999 N04E Well has serious scale problems. _ 1/22/2004 ~, I ryQTE: CORKSCREWED TUBING STARTING a~18659'WLM 8/31/2004 NQTE: WAWERED WELL: IAx OA COMMUNICATION 5/1/2008 NOTE: CORKSCREWED TBG FROM 8535' ~ ~ ~ ~.~ ~~ - `' STATE OF ALASKA ~ 4 r'i~~ ALASKA OIL AND GAS CONSERVATION COMMISSION A(~~"~ , REPORT OF SUNDRY WELL OPERATIONS ~. ~ ~~~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ `-` Alter Casing ^ Pull Tubing ~ ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ~ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ ~ Exploratory ^ 184-067 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20030-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 130' ~ 2A-05' 8. Property Designation: 10. Field/Pool(s): ADL 25570 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9185'- feet true vertical 6236' - feet Plugs (measured) 3485', 8591' Effective Depth measured 3485' feet Junk (measured) 8907' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 104' 16" 104' 104' SURFACE 3209' 9-5/8" 3209' 2619' PRODUCTION 9060' 7" 9060' 6152' Perforation depth: Measured depth: 8692'-8730', 8762'-8784', 8796'-8855' ~~ pp~~~~gy ~` rr'' ryrtt~g " ' ~~ vJ ldDD >r ~U~ ~ ~ LUUU true vertical depth: 5904'-5930', 5951'-5966', 5974'-6013' Tubing (size, grade, and measured depth) 2-7/g" kill string, Hydril 511, 3019' MD. Packers &SSSV (type & measured depth) pkr- BAKER'FHL' ; BAKER 'FB-1' pkr- 8568' ; 8781' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: none contact Brett Packer @ 265-6845 Printed Name Br ck er et t P a Title Wells Group Engineer % ~ ,- ~ ~ Signature ~/~~ ~`"' ~/~ Phone: 265-6845 Date ~~ ~f O Z Pre aced b Sharon Allsu -Drake 263-4612 Form 10-404 Revised 04/200 ~ ~ ~~~~~ ~ 208 Submit Original Only ~ ~~ ~~~~~ • r Cono~4t'hi~lips Time Log & Summary LYe/7Ykyy Vreb ReRwYfng Report __ -- __ Well Name: 2A-05 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/12/2008 12:00:00 PM Rig Release: 7/20/2008 3:30:00 PM Time Logs Date From to Dur S. Depth E Depth Phase Code Subcode T Cornment ____ 7/10/2008 24 hr Summary Move Nordic Rig 3 off 1 D-07 to 2A-05 16:00 17:00 1.00 COMPZ MOVE MOB P Move Nordic Rig 3 off 1 D-07 to Spine Road. 17:00 17:30 0.50 COMPZ MOVE WOEQ NP Waiting on Crane move to pass by 1 D Pad from Olicktok to Milne Point. 17:30 20:00 2.50 COMPZ MOVE MOB P Move rig from 1 D Pad to KOC 20:00 23:30 3.50 COMPZ MOVE WOEQ NP Stand by w/ crews while shuffling rig mats ahead of ri 23:30 00:00 0.50 COMPZ MOVE WOEQ NP Stand by w/ crews do to CPF 1 Shut down. 7/11 /2008 Continue to Move Nordic rig 3 to 2A-05 00:00 03:30 3.50 COMPZ MOVE WOEQ NP Continue to wait @CPF 1 for CPF 1 shutdown. Standb w/ ri crews 03:30 05:00 1.50 COMPZ MOVE MOB P Road rig from CPF 1 to 1A Pad access. 05:00 07:00 2.00 COMPZ MOVE WOCC P Waiting on CPAI Field Crew change. Standb w/ ri crews 07:00 14:30 7.50 COMPZ MOVE MOB P Road rig from 1A Pad to 1/2 mile ast 2B Pad and ri fell throu h road. 14:30 21:30 7.00 COMPZ MOVE OTHR T Jacking up and shoring up under rig moving system to drive upon rig mats. 21:30 22:00 0.50 COMPZ MOVE OTHR T Drive rig on mats and standby for additional mats to be laced. 22:00 22:30 0.50 COMPZ MOVE MOB P Continue to road rig to 2A Pad access road. 22:30 00:00 1.50 COMPZ MOVE OTHR P Move in and place mats on 2A Pad access road. 7/12/2008 Continue to move rig f/ 2A Pad access to 2A Pad on mats. MIRU, RU to circ to tiger tank. Pull BPV and o en u well. Circ to kill well. 00:00 02:00 2.00 COMPZ MOVE MOB P Continue to standby w/ crews. Settin mats on 2A accesss road. 02:00 02:30 0.50 COMPZ MOVE MOB P Move towards 2A Pad w/ rig on mats. 02:30 03:00 0.50 COMPZ MOVE MOB P Continue to standby w/ crews. Settin mats on 2A accesss road. 03:00 03:30 0.50 COMPZ MOVE MOB P Roll back on double mats for shuffle. 03:30 05:00 1.50 COMPZ MOVE MOB P Continue to standby w/ crews. Settin mats on 2A accesss road. 05:00 05:30 0.50 COMPZ MOVE MOB P Move towards 2A Pad w/ rig on mats. 05:30 06:00 0.50 COMPZ MOVE MOB P Continue to standby w/ crews. Settin mats on 2A accesss road. -~ - - F'~c~~ 1 caf ? • • Time Logs __ _ _ __ -. ~' Date From To Dur S De th E De th Phase Code Subcode T Comment _ 06:00 09:00 3.00 COMPZ MOVE MOB P Move towards 2A Pad w/ rig on mats. 09:00 10:00 1.00 COMPZ MOVE DMOB P Continue to standby w/ crews. Settin mats on 2A accesss road. 10:00 10:30 0.50 COMPZ MOVE MOB P Continue to standby w/ crews. Settin mats on 2A Pad 10:30 12:00 1.50 COMPZ MOVE MOB P MIRU on 2A-05, spot and level rig. Berm up. Acce t ri 12:00 hrs on 7/12!08 12:00 15:30 3.50 COMPZ RPCOM OTHR P Spot equipment. RU auxiliary equipment. Lubricate out BPV. Load pits w/ 510 bbls of 9.6 ppg Brine. 15:30 17:00 1.50 COMPZ WELCTL CIRC P RU circ lines from tiger tank to Tree and PT all um lines 2,500 si. 17:00 18:30 1.50 COMPZ WELCTL CIRC P Open up well 400 psi tbg psi, 100 psi IA Psi, 50 psi OA Psi.; Bled the tbg pressure off to 0 and the IA pressure to 0. Circulate well over to 9.6 brine. 18:30 20:30 2.00 COMPZ WELCTL OTHR P Monitor well. Slowdown hardline to tiger tank looking for restriction. Disconnect from rig and inspect for restrictions. Re assemble and PT @ 2,000 si. 20:30 21:00 0.50 COMPZ WELCTL CIRC P Open well up to choke and bled down f! 310 psi. Load well w/ 9.6 ppg brine w/ centrifugal pump returnin as and fluid. 21:00 22:00 1.00 COMPZ WELCTI OWFF P SWI and Monitor 22:00 23:00 1.00 COMPZ WELCTL CIRC P Open tbg 370 psi SITP, 270 psi. SICP. Monitor 23:00 23:30 0.50 COMPZ WELCTL CIRC P Reverse circ. ICP @ 310 psi @ 2 bpm pressure increased to 730 psi @ same rate then dropped to 340 si. 23:30 00:00 0.50 COMPZ WELCTL OWFF P Monitor well. 7/13/2008 Continue to circulate to kill well -migrating gas form below GLM depth. Set F type BPV -failed. Rih w/ WFT WRP and set @ 94' - PT @ 2,500 psi for 15 minutes. ND Tree and inspect lifting threads. NU and Test ROPE @ 250/2,500. 24 hr Notice was given @ 14:45 hrs on 7-10-08. Update was given @ 16:35 hrs on 7-11-08. Witness of test was waived b Jeff Jones 16:45 hrs on 7-11-08 00:00 01:00 1.00 COMPZ WELCTL OWFF P Continue to monitor well. 01:00 02:00 1.00 COMPZ WELCTL CIRC P RU to Reverse circ. after getting gas back, ICP 190 psi @ 2 bpm - increase pump rate to 5 bpm @ 1,900 psi. Had pressure drop 1,200 strokes to 1,680 psi at the same um rate, FCP 1,820 si 5 b m. 02:00 02:30 0.50 COMPZ WELCTL OWFF P Monitor well and verify well is dead. 02:30 03:30 1.00 COMPZ WELCTL OTHR P Set BPV 03:30 04:00 0.50 COMPZ WELCTL OTHR P Bleed down control line, ND tree Pale 2 of T • • Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment 04:00 07:00 3.00 COMPZ WELCTL NUND P Stop ND of Tree due to a leaky BPV. _ Brim lubricater to floor, RU and pull faulty BPV showed to have 40 psi below valve. Check SSSV, insure valve is o en - verified b Pad OP. 07:00 12:00 5.00 COMPZ WELCTL CIRC P RU to circulate and circulate down tbg @ 3 bpm @ 675 psi. Monitoring well for flow after each BU. 12:00 12:30 0.50 COMPZ WELCTL OWFF P Monitor well for flow. 12:30 17:00 4.50 COMPZ WELCTL OTHR P Held PJSM w/ HES Slickline. RU Lubricator and PT @ 500 psi. Rih an '. Pooh and RD Slick line. PT TBG @ 2,500 psi for 15 minutes.. 17:00 19:30 2.50 COMPZ WELCTL NUND P ND Tree, clean and inspect hanger threads. Install test dart. 19:30 22:30 3.00 COMPZ WELCTL NUND P NU BOPE 22:30 00:00 1.50 COMPZ WELCTL BOPE P Test BOPE @ 250/2,500 psi. 24 hr notice was given to the AOGCC @ 14:45 hrs on 7-10-08. Update was given @ 16:35 hrs on 7-11-08. Witness of test was waived @ 16:45 hrs on 7-11-08. 7/14/2008 Continue to Test BOPE @ 250/2,500. 24 hr Notice was given @ 14:45 hrs on 7-10-08. Update was given @ 16:35 hrs on 7-11-08. Witness of test was waived by Jeff Jones @ 16:45 hrs on 7-11-08. Pull test plug. RU Slick line and retreive WRP @ 94'. BOLDS and Pull on pipe to 150k max, unable to pull seals. RU HES and drift run TBG unable to drift above 2.125" OD. RU Eline and strip shot Seals ass Attem t to ull free. 00:00 04:00 4.00 COMPZ WELCTL BOPE P Continue to Test BOPE @ 250/2,500 si. RD Test a ui ment. 04:00 04:30 0.50 COMPZ RPCOM OTHR P Pull test dart and MU Landing jt. 04:30 07:30 3.00 COMPZ RPCOM SLKL P held PJSM and RU Slick line. Rih and equalize WRP @ 94'. Pooh and Chan a over to Reteivin tool. Release WRP and Pooh. Hang Back HES. 07:30 09:00 1.50 COMPZ RPCOM CIRC P BOLDS, hanger moved up 6". Upland hanger and pull up to 150k no movement. Come back down and set down 3' off w/ hanger. Work pipe while circulatin 3 b m 560 si. 09:00 18:30 9.50 COMPZ RPCOM SLKL P Held PJSM w/HES. RU Lubricator, Rih w/ 2.625" OD. Drift down to 106'. Pooh and swap drift over to 2.45" OD Drift and Rih to 227' and set down. Change out to 2.125" OD, Rih to 217' and work thru to 264'. Pooh and change out to 1.5" OD and Rih to 8,561'. Pooh and change out to 1.875" OD and Rih to 1,000'. Pooh and RD Slick line unit. Through out the drift runs attempts were made to change the dynamics of the hole by pumping and changing slack off wei hts. Page ~ oaf ? • Time Logs Date From To Dur S. De th E_ De th Phase Code Subcode T Comment 18:30 20:30 2.00 COMPZ RPCOM WOEQ P Wait on Primer cord for Schlumber er and RU SLB. 20:30 23:30 3.00 COMPZ FISH ELNE P Held PJSM and MU SLB 12' string shot and shot of 8 552' to 8 564'. Pooh and RD SLB. 23:30 00:00 0.50 COMPZ FISH OTHR P Work TBG pulling up to 150k max. 7/15/2008 Continue to attempt to pull seals. Make drift runs to 500' w/ 2.80 mill. Cut tbg at 8,536', POOH LD tubing to SSSV, attem ted to run cs saved a throw h ti ht s of at 220'. 00:00 01:30 1.50 COMPZ FISH OTHR P Continue to work up to 150k attem tin to ull seals. 01:30 03:00 1.50 COMPZ FISH PULD P PU 2.125" OD Motor asst' w/ 2.30" OD mill and Rih PU 1" CS Hydril tbg to 520' w! no restrictions. Pooh. 03:00 04:30 1.50 COMPZ FISH PULD P Change Mill to 2.80" OD and Rih to 520' w/ no restrictions. Pooh. 04:30 05:00 0.50 COMPZ FISH OTHR P MU landing jt. w/ TIW Valve. 05:00 11:30 6.50 COMPZ FISH ELNE P W/O Eline to arrive for them cut @ 8,536'. RU and Rih w/ 2.125" OD Extended Reach Chemical cutter to 8,562' and correlate. Set CCL @ 8,523.7 and Cut TBG @ 8,536' (cut will accept 3 5/8" overshot). 12.3' CCL to Cutter. Pooh and RD Eline. Note: Set down high the first time in the PBR then was able to get deeper the second time to 8,562'. 11:30 12:00 0.50 COMPZ FISH OTHR P U to drive and Pull to 120k. 5k over u wt and ull free. 12:00 14:00 2.00 COMPZ RPCOM CIRC P Reverse circulate @ 4 bpm 60 psi 1 1/2 volumes- switch and circulate down the tbg @ 8 bpm @ 1,020 psi, FCP 8 b m 1,120 si. 14:00 16:30 2.50 COMPZ RPCOM CIRC P LD landing jnt and hanger, tubing was flowing, made up head pin and CBU @ 5 bpm - 450 psi, tubing still flowin ,mixed and um ed d 'ob. 16:30 20:30 4.00 0 6,584 COMPZ RPCOM PULD P POOH w/ 3 1/2" completion., up weight 105K, LD SSSV, up wt 90K, down wt 60K. SSSV had small amount of metal shaved from csg lodge on top shoulder due to tight spot in csg at +/- 210'. Decision was made to RIH with Baker csg swedge made up on top of remaining tubing string for additional string weight, 3 1/2" DP and 4 3/4" DC's. 20:30 21:30 1.00 6,584 6,584 COMPZ RPCOM OTHR P Racked and tallied 41 juts 3 112" DP and 6 'nts 4 3/4" DC's. C~~r~e 4 of 7 • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 21:30 23:00 1.50 6,584 6,584 COMPZ RPCOM PULD P MU 6 1/8" Baker csg swedge, jars and XO's, singled in holes with 6 jnts DC's and 1 jnt DP from shed to swedge depth of 220'. Tagged tight spot at 220', worked through tight spot to swedge depth of 242' up wt 105K, down wt 60K. Worked swedge 2x to 242' on 3rd attem t could not et ast 225'. 23:00 23:30 0.50 6,584 6,584 COMPZ RPCOM TRIP P POOH stnd back DC's in derrick, LD Baker saved a BHA. 23:30 00:00 0.50 6,584 6,584 COMPZ RPCOM P RU handling equipment to cont LD 3 1/2" completion. Fluid loss for last 24 hrs=0 7/16/2008 POOH LD 3 1/2" completion. R/U and run caliper log. Attempted to RIH W/muleshoe, stopped @ 240', POOH. RIH and set IPB 3,483' 00:00 07:30 7.50 6,584 0 COMPZ RPCOM PULD P Cont POOH LD 3 1/2" tbg from 6,584'. 07:30 09:00 1.50 COMPZ RPCOM OTHR P Unload pipe shed and take pies of 18' cut jt. Clear rig floor and install wear rin . 09:00 15:30 6.50 COMPZ RPCOM SFTY P Held PJSM w! HES on caliper log. RU and Rih w/Memo Caliper Logging equipment to 8,500' and log out of the hole. RD HES. Download and send logs to Houston Field Review l0 243' for 1' from 6.1" ID to 5.97" ID and 254' for 3' from 6.1"ID to 5.63"ID 15:30 16:00 0.50 0 0 COMPZ RPCOM TRIP P MU muleshoe, 6 - 4.75 OD DC's, & Rih PU DP and was not able to get past 225'. POOH and LD DP and stand back DC's. 16:00 23:30 7.50 3,485 0 COMPZ FISH ELNE XP Call out Eline and Baker TT. M/U tools &RIH, Set IBP @ 3,485'. POOH w/ wireline and RD 23:30 00:00 0.50 0 0 COMPZ FISH ELNE XP R/U to run 2.875" 511 tubing 7/17/2008 Continue to RIH w/2.875" 511, lay 250# of sand on top of IBP. POOH LD 2 7/8" hydril 511. ND BOPE & stand back. Start ND tubin head. 00:00 06:00 6.00 0 3,417 COMPZ FISH PULD XP R/U to run 2.875" 511 tubing. Tight f/ 415' to 3,417' 85k u wt 40k do wt. 06:00 07:30 1.50 3,417 3,417 COMPZ FISH OTHR XP Dump 6 sxs or 300# of sand 07:30 08:00 0.50 3,417 3,483 COMPZ FISH OTHR XP Rih and attempt to tag sand -tag up @ 3,483' Top of IBP, sand had not settled et. 08:00 13:00 5.00 3,483 0 COMPZ FISH PULL XP Pooh laying down 2.875" HYD 511 13:00 18:00 5.00 0 0 COMPZ WELCTI NUND XP Pull wear ring and ND BOPE 18:00 00:00 6.00 0 0 COMPZ WELCTL NUND XP ND tubin head with 7" cs risin out of cs head a rox 1'. 7/18/2008 ND tbg head, spear 7" csg, reset Vetco Grey csg slips, cut and dress csg stub, NU new FMC tbg head, NU BOP and shell test, make 6 1/8" swa a run, POOH, S&C drill line. Pace 5 of ?' • • Time Logs _-- __ _ Date__ From To Dur S. De th E_ De th Phase Code Subcode T Comment_-____ _ 00:00 04:30 4.50 0 COMPZ RPCOM NUND XP MU 1 jnt 4 3/4" DC and test plug, stab into tbg head, cont ND tbg head. 7" Csq rose 22 1/8" total. Remove tbg head and seals, prep ack off for removal. 04:30 07:30 3.00 COMPZ FISH PULL XP PU 5 3/4" Bowen Itco spear, GR, spear extension, spear stop sub w/ 8 3/8" stop ring. Pul- to 315k and attem t to work slack from 7" 26# cs strin . 07:30 09:30 2.00 COMPZ FISH OTHR XP Install 7" Vetco Gray Slips and land 7" 26# cs 100k in sli s. 09:30 10:00 0.50 COMPZ RPCOM HOSO XP Cut off 42" of 7" 26# Csg. Install Vetco Gra ack off. 10:00 14:30 4.50 COMPZ RPCOM NUND XP NU FMC Gen 3 Retro TBG Head. 14:30 15:00 0.50 COMPZ RPCOM SFEQ XP PT inner csg pack off to 3,000 psi and hold for 15 minutes. 15:00 18:30 3.50 COMPZ RPCOM NUND XP NU BOPE 18:30 20:00 1.50 COMPZ WELCTL BOPE XP RU and test 4 1/2" LPR's at 250 psi low and 2,500 psi high. RD test equipment. State was notified on 7-14 at 13:00 hrs and witness was waived by AOGCC rep Jeff Jones at 19:10 hrs 7-14. 20:00 21:00 1.00 COMPZ RPCOM OTHR XP Set wear ring, R&T 3 1/2" DP, RU floor a ui ment for 3 1/2 DP. 21:00 22:30 1.50 0 223 COMPZ RPCOM TRIP XP PJSM, PU and MU 6 1/8" swage w/ 4 3/4" DC's and RIH to 223'. Numerous attem is to work throu h tight spot at 223' but could not get throu h. POOH and LD 6 1/8" swage, MU 6" swage and run assem in hole. 22:30 00:00 1.50 0 0 COMPZ RIGMNT SVRG P RU and cut and slip 84' drill line. 7/19/2008 Obtain cement bond log w/ SWS, run kill string. 00:00 01:00 1.00 0 COMPZ RIGMNT RGRP P Cont slip and cut drill line, replace deadman clam studs. 01:00 02:00 1.00 0 283 COMPZ RPCOM TRIP XP PU and MU 6" swage assembly and RIH to 283' pushing pipe with top drive. Collars dragging and could not activate bum er sub. 02:00 02:30 0.50 283 283 COMPZ RPCOM OTHR XP Call HSL for caliper run, offload i eshed. 02:30 04:00 1.50 283 0 COMPZ RPCOM TRIP XP POOH LD 4 3/4" DC's and 6" swage assembl . 04:00 08:00 4.00 COMPZ RPCOM SLKL XP RU HSL for caliper run, Field review showed that buckling of 7" CSq was alot less than revious to . 08:00 09:00 1.00 COMPZ RPCOM OTHR XP Clean rig floor and kick out tubing and change over to Rih w! 4.5" Com letion. Wearin bushin . 09:00 09:30 0.50 COMPZ RPCOM DHEO XP PT 7" 26# J-55 csg to 2,500 psi to 3,484' and chart for 30 minutes. 09:30 11:00 1.50 COMPZ RPCOM OTHR XP Load completion equipment in pipe shed. Pale 5 of 7 L Time Logs _ _ _ Date Frorn_ To Dur S. De th E. De th Phase Code Subcode T Comment _ 11:00 14:00 3.00 0 0 COMPZ RPCOM PULD XP PU and Rih w/ 4 1/2 completion as per run tally to 207' and set down. Pooh la in down 4 1/2 com letion. 14:00 14:30 0.50 0 COMPZ RPCOM OTHR XP Install wear ring, Clean and clear rig floor. 14:30 21:00 6.50 COMPZ EVALWE ELOG XP RU Schlumberger to run USIT log from 3,437' to surface. Rih w/ logging tools w/ 4.625" OD x 6" bottom and set down @ 275' ELM. Pooh and change over to Rih w/ 1 11/16" OD SCMT. RIH to 3,450' WLM and log OOH to 150'. TOC @ 1,970'. Changed LPR's to 2 7/8" while chan in out SCM tool. 21:00 21:30 0.50 COMPZ WELCTL OTHR XP Pull wear ring, install test plug. 21:30 23:30 2.00 COMPZ WELCTI BOPE XP RU and test LPR's 250 psi low, 2,500 psi high. LD test jnt and test plug, RD test equipment. Witness waived by AOGCC rep Chuck Scheve at 17:00 hrs on 7-19-08. 23:30 00:00 0.50 0 88 COMPZ RPCOM RCST XP RU and PU RIH w/ 2 7/8" Hydri1511 kill strip to 88'. 7/20/2008 RIH w/ 2 7/8" Hydril 511 kill string, ND BOP and change LPR's, NU and test tree, RU and freeze protect well, RDMO. Released Nordic Ri 3 15:30 on 7-20-08 00:00 03:00 3.00 88 3,019 COMPZ RPCOM RCST XP Cont PU RIH with Hydril 511 kill strip from 88' to 3 018'. 03:00 03:30 0.50 3,019 3,046 COMPZ RPCOM HOSO XP MU XO's and 11" x 4.5" IBT hanger on landing jnt, land hanger, up wt 52K - dwn wt 43K, RILD's, LD landin 'nt, install 2 wa check. 03:30 07:00 3.50 3,046 3,046 COMPZ RPCOM NUND XP PJSM, ND BOP and change out LPR's to 3 1/2". 07:00 08:30 1.50 3,046 COMPZ RPCOM NUND XP NU Tree 08:30 09:30 1.00 COMPZ RPCOM SFEQ XP Test void to 5,000 psi and hold for 15 minutes. PT Tree @ 250/5,000 and hold for 10 minutes. 09:30 11:30 2.00 COMPZ RPCOM FRZP XP Held PJSM w/ LRS. RU lines and freeze protect wellbore w/ 108 bbls diesel. Freeze protect OA bullheadin w/ 6 bbls diesel. 11:30 15:30 4.00 COMPZ RPCOM RURD XP RD, BD all equipment, clean pits, make ready for rig move. Back rig off well and clean cellar Release Nordic Rig 3 @ 1530 hrs. IA: 0 psi OA: 0 psi Tb : 0 si Page 7 ~f ~ w _ / J ~' N0.4792 Schlumberger -DCS 2525 Gambell Street, Suite 400 ~U~ ~ ~~~~ Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838~,~ ~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 07/24/08 1A-06 12080402 INJECTION PROFILE ~ - ( 07/06/08 1 1 3C-17 11964626 SFRT qg- 07/12/08 1 1 1Y-04 12096505 INJECTION PROFILE - - t, 07!13/08 1 1 i G-O6 12061729 INJECTION PROFILE a d 07/13/08 1 1 1 F-06 12096506 PRODUCTION PROFILE - ( 07/14/08 1 1 3M-08 12096516 SBHP SURVEY 07/21/08 1 1 3M-09 12096515 SBHP SURVEY (P (p 07/21/08 1 1 3N-13 12096517 SBHP SURVEY ~=C. (o - 07/22/08 1 1 2W-01 12096508 PRODUCTION PROFILE ~ 07/16/08 1 1 1 F-06 12096510 PRODUCTION PROFILE - /C 07/17/08 1 1 2A-02 12096511 INJECTION PROFILE (~Z 07/18/08 1 1 3J-17 12096514 SBHP SURVEY ' g /~{Q ~- ~ , 07/20/08 1 1 3J-07A 12097409 ®(~(~'~~ SBHP SURVEY O t_~~~ 07/20/08 1 1 3C-15A 12097406 USIT I / '~ 07/17/08 1 1 2A-05 12096512 SCMT l.(- 07/19/08 1 1 n Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 2A-OS Workover status Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, July 21, 2008 3:45 PM To: 'Packer, J.Brett' Subject: RE: 2A-05 Workover status • Page 1 of 3 ~~sy-o~`1 Brett, As discussed, a contact should have been made when it was determined that the work would be halted and the well secured. It does appear that the well was properly secured. A sundry will be needed for the next phase of the work. If you've not already done so, I'd suggest you contact Dave Reem at BP. They have been doing a lot of cut and pulls from about 2000'. I will get back to you with regard to a 403. Sort of superfluous now. Yes, a 404 should be sent with "pull tubing and operations SD" checked. Call or message with any questions. Tom Maunder, PE AOGCC From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, July 21, 2008 3:32 PM To: Maunder, Thomas E (DOA) Subject: 2A-05 Workover status ~~~~~ .JUL ~ ~ Z~a$ Tom, As per our discussion, here's a summary of the Workover events on 2A-05 which led up to the decision to move off the well and come back to it at a later date. History 2A-05 was originally drilled as a selective single injector for the CPF2 gas storage area back in 1984. In 1987, it was converted to a producer and flowed without gas lift until August 2006 due to only having one deep circulation GLM. In August 2006, we perforated the tubing and installed two POGLM's (packoff gas lift mandrels) to facilitate gas lift. It failed a TIFL earlier this year and due to a tight spot in the tubing at 200', we could not repair it, so the well was shut-in. The well has a WRP set in the tubing below the top packer at 8591' RKB and it passes a CMIT. The scope of the Workover was to pull the current 3-1/2" completion above the top packer, and upsize to 4-1/2" with a new gas lift design. 7/12108: Accepted Rig at 12:00 hrs. Circulated in 9.6 brine. 7/13/08: Had a leaky BPV, and no replacement on the slope (old style 'F' BPV), so rigged up Slickline to set a WRP at 94' RKB so that we could ND the tree and NU the BOPE. Tested BOPE. 7114/08: Pulled WRP at 94' RKB. After we backed out the lock down screws on the hanger, the hanger moved up 6"due to tubing being in compression. We pulled on the tubing trying to pull the seals from the PBR, but no luck. When we set back down, the tubing came to rest 3' above it's original position. We rigged up Slickline to drift the tubing for a chemical cut. We ran in with a 2.625" OD and it drifted to 106' and stopped. We tried a 2.45" OD and drifted to 227' and stopped. We tried a 2.125" OD and drifted to 217' and worked it to 264' and stopped. Tried a 1.5" OD and drifted all the way to bottom. Swapped over to a 1.875" OD and drifted through tight spot down to 1000'. So our tight spot is between 200-300' deep. We rigged up E-line and RIH w/ a string shot and 7/22/2008 2A-OS Workover status • • fired it across the PBR hoping to free it up, but no luck. Page 2 of 3 7/15/08: RIH w/ a 2.125" motor and 2.30" mill down to 520' no problems. Switched to a 2.80" mill and ran into 520' no problems. So we rigged up E-line and RIH w/ a 2.125" chemical cutter and cut the tubing at 8536' RKB. We pulled 5K Ibs over string weight and it came free, good cut. POOH w/ completion until SSSV was at surface, laid dawn the SSSV. Then decided to RIH w/ a 6-1/8" swage on top of the remaining completion for added weight below the swage. RIH w/ swage to 220' and worked to 242'. Could not get any further. 7/16/08: POOH w! swage and remainder of the 3-1/2" tubing. Rigged up Slickline and ran amulti-fingered caliper tog ftom 8500' to surface. RIH w/ a Muleshoe and 4-3/4" drill collars and couldn't get drill collars past 225'. Rigged up E-line and set an IBP at 3485' RKB. 7117/08: RIH w/ 2.875" Hydri1511 tubing to 3417', tight from 417' down. Dumped 300# of sand on top of IBP. POOH w/ 2.875" Hydril 511. ND tubing head. 7/18108: As the tubing head bolts were loosened, the 7" casing grew 22.125". Latched onto the 7" csg. w/ a spear and pulled to 315K Ibs and held for a while. Redressed the slips and set the 7" back in the slips w/ 100K in slips. Cut off 42" total from the 7" casing. NU new tubing head (for the 4-1/2" completion) NU BOPE & tested. Tried to swage the casing w/ a 6.125" swage after straightening out the casing but still couldn't get past 223'. 7/19/08: Tried a 6" swage but couldn't get past 283' pushing it with the top drive. RU Slickline for another multi- fingered caliper log to compare to before. 2nd caliper indicated we had taken some of the buckling out of the casing but not all. Pressure tested the 7" casing to 2500 psi and charted it for 30 min. We tried to drift in with the completion (overshotlpacker, etc.) because all indications were we could get bigger OD tools through there so long as they weren't very long, we were just having trouble getting stiff collars and long rigid tools through the bends, after all, we managed to pull the SSSV (5.9" OD) and the bottom GLM (5.4" OD) out of the casing originally. But alas, the completion stopped at 207' and would not go further. At this point, we realized that we weren't going to be able to complete this well without cutting and pulling or backing off the casing. So, we decided to run a cement bond log to gain information about where the cement top is behind the 7" casing since it was Arctic Pak'd back then. We tried running a 4.625" OD USIT log w/ a 6" bottom, and it set down at 275'. So we ended up going with a 1-11/16" OD SCMT log. We logged from 3450' to surface and determined the top of cement to be at 1970' (surface casing shoe at 3209'). We decided to run a 2-7/8" Hydril 511 kill string in the well, as a casing repair would be a complete change in scope and we didn't feel comfortable trying to come up with a plan on the fly. We'd rather have some time to get a plan in order, and come back to this well when we are better prepared to deaf with this problem. 7/20/08: Changed out the pipe rams to 2-7/8" & tested. RIH w/ 3019' of 2-7/8" Hydril 511, landed hanger, RILDS, set 2-way check, ND BOP, NU tree 8~ tested. Freeze protected and RDMO. Rig released at 15:30 hrs. Current Status: The well has a WRP set at 8591' RKB, an IBP set at 3485' RKB, 300# sand on top of IBP and 3019' of 2-7/8" Hydril 511 kill string in the well. This is a good well, one we can't afford to lose, so we will be coming back to it hopefully within a couple months when we have a better plan on how we are going to go about fixing this 7" casing. 1 apologize for not notifying you in advance as we didn't plan on this outcome. We are not intending this to be a long-term shut-in well, nor do we consider it to be temporarily abandoned, it has just become one of those two- step workovers. This is actually a very informative well, as we have a few others on 2A and 2T pads that have seen similar subsidence and trouble getting past 200' MD. This has opened our eyes as to what to expect on these other workovers, so once we get all our ducks in a row and decide on a plan of attack, we will work that into the future Workover plans of those other wells too. We will be submitting the 10-404 as standard procedure; please let me know if you will need a 10-403 and I will get it to you right away. Thanks, '7/22/2008 2A-OS Workover status • • ,~ Brett 2'ac(gr ~DriCCng ~ `GVetZs zNorkaver~Engineer `Work# 265-6845 CeCC# 230-8377 Page 3 of 3 7/22/2008 • • ~V~~ f V/ V/! ProActiv+~ Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fay (907) 245-8952 1) Caliper Report 19-JuF08 2A-05 1 Report / EpE 50-103-20030-00 2) ~~~,~~f ~~ AU G ~. ~ 2008 lJ~ ~ ~ ~~ ~~ #~~ -~ Signed Print Name: Date PROACTNE DIAGNOSTIC SERVICES, M/C., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245.8951 Fax: (9071245-88952 E-MAIL ~~ __ ~ ~~_~ WEBSITE " -- - ---- 3~ C:\Documents and Settingsl0wneilDesktop\Transmit Conoco.doo • e Memory Mufti-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: ZA-05 Log Date: July 19, 2008 Field: Kuparuk Log No.: 8698 State: Alaska Run No.: 3 API No.: 50-103-20030-00 Pipet Desc.: 7" 26 Ib. J-55 Top Log Intvl1.: Surface Pipet Use: Production Casing Bot. Log Intvl1.: 3,440 Ft. (MD) ' Inspection Type : Mechanical Damage /Restriction Inspection COMMENTS : ` ~j This call er data is tied into the Casin Han er 0' Driller's De th . ~ ~ ~ ~ J O ~ 4 ~ " ~~ N ~- ~ Gv ( N ) ,~' This log was run to assess the condition of the production casing logged with respect to mechanical damage and minimum I.D. restrictions following operations to correct buckling. This is the third time a PDS caliper has been run on this well and the second time the 7" production casing has been logged. The caliper recordings indicate a reduction in the frequency and severity of the buckling reported in the previous log (July ' 16, 2008) throughout the interval logged. Bends in joint 6 (194') and joint 5 (188') restrict the minimum I.D. to 6.09" and 6.17" respectively. A 3-D log plot of these bends is included in this report. A graph illustrating the minimum I.D. recorded on a joint-by joint basis is included in this report. ' The caliper recordings indicate the 7" production casing logged appears to be in good condition with respect to corrosive damage. No significant wall penetrations (> 6%) or areas of cross-sectional wall loss (> 1 %) are recorded throughout the production casing logged. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 6%) are recorded throughout the production casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 1 %) are recorded throughout the production casing logged. MAXIMUM RECORDED tD RESTRICTIONS Bend Minimum I.D. = 6.09" Jt. 6 @ 194 Ft. (MD) Bend Minimum I.D. = 6.17" Jt. 5 @ 188 Ft. (MD) No other significant I.D. restrictions are recorded throughout the production casing togged. Field Engineer: K Miller Analyst: HY. Yang Witness: R. Dolcater ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-05 Date : July 19, 2008 Description : Detail of Caliper Recordings Across Interval of Bends • ~ ~~ Minimum Diameter Profile ~ ti Well: 2A-05 Survey Date: )uly 19, 2008 Field: Kuparuk Tool: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 6.276 inches Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 33 35 37 39 41 E a3 Z as = 47 •~ 49 s1 53 55 57 59 61 63 65 67 69 71 73 75 77 79 81 83 85 87 89 I 1 1 ^ f I t 1 1 1 1 1 1 I t 1 1 1 1 1 1 1 ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ r ^ ^ ^ ~ ~ ^ i ^ w• ^ i I ~ ^ ^ ~ ^ I ^ I ~ ^ ^ i ~ ^ ^ ^ ^ ^ ^ ^ • Correlation of Recorded Damag Pipe 1 7. in (-0.0' - 3400.5') Well: Field: Company: Country: Survey Date: i ;e to Borehole Profile 2 A-05 Kuparuk ConocoPhilips Alaska, Inc. USA July 19, 2008 ^ A pprox. Tool De viation ^ Approx. Borehd e Profil e 1 -0 10 347 20 732 30 1123 40 1517 ~ v E ~ ~ ._ z s ~ 50 ~ 1904 aQ, o p 60 2285 70 2672 80 3057 89 3401 0 5 0 1 00 Da mage Pr ofile (% wall) / Tod Deviatio n (degr ees) Bottom of Survey = 89 • • PDS Report Overview ~, ~~ Body Region Analysis Well: 2A-05 Survey Date: July 19, 2008 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f -55 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 100 80 60 40 20 0 0 to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of ~oints anal sed total = 89 pene. 4 85 loss 75 14 0 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body ;- metal loss body 0 50 100 1 21 41 61 81 Bottom of Survey = 89 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 7. in 26.0 ppf }55 Well: 2A-05 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company. ConocoPhilips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: July 19, 2008 Joint No. Jt. Depth (Ft.) f'e°n. UpcE~1 Ilnti.) Pen. Body (Ins.) f'en. % Metal Ir,a °'° Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 -0 t! 0.02 5 1 6.22 2 39 ~) 0.01 3 1 6.25 3 75 U 0.01 i 1 6.25 4 113 U 0.01 .~ 1 6.24 5 153 ~! 0.01 ~ I 6.17 Bend. 6 190 U 0.01 a I 6.09 Bend. 7 229 I! 0.01 ! 6.20 Bucklin . 8 269 I~ 0.01 _' I 6.22 9 308 t~ 0.01 y ~! 6.25 10 347 ~? 0.01 2 0 6.23 11 384 0 0.01 3 U 6.24 12 421 l) 0.01 3 I 6.24 13 459 I! 0.01 ~ I 6.24 14 498 ~~ 0.01 ~' i~ 6.22 15 538 t! 0.01 3 I 6.25 16 575 U 0.01 ~ I 6.22 17 615 U 0.01 ; I 6.24 18 654 l) 0.01 4 I! 6.24 19 693 U 0.01 i I 6.24 20 732 t! 0.01 ~ r! 6.22 21 772 !) 0.01 ~ I 6. 4 22 811 0 0.01 ~ I 6.23 23 850 U 0.01 2 1 6.25 24 888 ~! 0.01 ?' I 6.24 25 927 U 0.01 ~ I 6.2 Sli t Bucklin . 26 967 U 0.01 ~' a 6.24 27 1006 U 0.01 3 I 6.24 28 1045 t) 0.01 ~ I 6.23 29 1085 a 0.01 3 I 6.23 30 1123 U 0.01 ~! 6.24 Sli t Bucklin . 31 1163 (! 0.01 ~ I 6.24 32 1201 0 0.01 ? U 6.24 33 1241 c! 0.01 3 I 6.24 Sli t Bucklin . 34 1280 0 0.01 3 I 6.20 Bucklin . 35 132 0 0.01 t I 6.21 36 1358 U 0.01 ~i I 6.23 37 1398 t! 0.01 4 1 6.22 38 1438 t! 0.01 ~ I 6.21 3 1477 a 0.00 1 I 6.23 40 1517 U 0.01 Z 1 6.22 41 1557 (! 0.01 ~ 1 6.21 42 1595 a 0.02 6 2 6.21 43 1635 0 0.01 3 2 6.20 44 1674 t! 0.01 4 I 6.21 45 1714 r) 0.01 ~~ I 6.2 46 1752 ~! 0.01 i 1 6.22 47 1790 ! ! 0.01 I 6.21 48 1828 U 0.01 I 6.20 49 1864 U 0.00 1 I 6.20 Sli t Bucklin . 50 1904 !! 0.01 3 Z 6.20 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf }55 Well: 2A-05 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company. ConocoPhiYips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: July 19, 2008 Joint No. Jt. Depth (Ft) I'~~n. Ulsct (lns.) Pen. Body (Ins.) P~~n. °/> ~tilc~l.~l Loss ",', Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 1942 O 0.01 3 1 6.21 52 1978 t) 0.01 1 I 6.20 53 2018 l) 0.01 i ~' 6.19 54 2054 t) 0.01 ~ I 6.20 55 2094 U 0.01 ? 1 6.21 56 2132 U 0.01 3 1 6.21 57 2172 f) 0.01 t 6.21 58 2209 l) 0.01 ~ 6.21 59 2247 (? 0.01 I 6.19 60 2285 a 0.01 _' I 6.20 61 2324 U 0.01 3 6.21 Sli t Bucklin . 62 2363 U 0.01 ~~ I 6.22 Bucklin . 63 2399 (1 0.00 1 I 6.23 64 2437 a 0.01 ~ 1 6.21 65 2475 O 0.01 3 I 6.22 66 2515 a 0.01 ~ I 6.21 Bucklin . 67 2555 t) 0.01 2 I 6.22 68 2593 c) 0.01 ~ I 6.21 69 2632 c) 0.01 7 I 6.21 70 2672 l) 0.01 ~ I 6.20 71 2710 t) 0.01 _' I 6.22 72 2 749 U 0.01 2 I 6.20 73 2787 O 0.01 2 1 6.20 74 2825 O 0.01 3 1 6.21 75 2864 U 0.01 3 _' 6.21 76 2901 t) 0.01 t 1 6.21 77 2941 t) 0.01 6.20 78 2981 t) 0.01 _' I 6.21 79 3020 t) 0.01 ~ I 6.20 80 3057 t) 0.01 i I 6.19 Bucklin . 81 3097 U 0.01 i I 6.18 Bucklin . 82 3135 t) 0.01 ~ _' 6.18 Bucklin . 83 3174 t) 0.01 i _' 6.18 84 3211 t) 0.01 ) 6.18 85 3249 t 1 0.02 ~ 6.17 86 3287 U 0.01 _' 6.18 87 3326 l1 0.01 3 I 6.18 Bucklin . 88 3363 l) 0.01 4 1 6.21 Bucklin . 89 3401 U 0.01 3 1 6.20 Bucklin . Penetration Body Metal Loss Body Page 2 ~ `S PDS Report Cross Sections Well: 2A-05 Survey Date: July 19, 2008 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA N'o. of Fingers: 40 Tubin 7 ins 26 f -55 _ Analyst: HY. YanQ Cross Section for Joint 6 at depth 194.417 ft Tool speed = 67 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 100 Tool deviation = 1 ° Finger 37 Projection = -0.158 ins Bend Minimum I.D. = 6.09 ins. HIGH SIDE = UP r • Cross Sections page 1 ~ ~ ~ ~ ~ ^~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ _ ~ PDS Report Cross Sections Well: 2A-05 Survey Date: July 19, 2008 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: Z.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f -55 Anal st: HY. Yan Cross Section for Joint 5 at depth 188.22 ft Tool speed = 72 Nominal ID = 6.2 76 Nominal OD = 7.000 Remaining wall area = 100 Tool deviation = 3 ° Finger 29 Projection = -0.11 ins Bend Minimum I.D. = 6.17 ins. HIGH SIDE = UP • Cross Sections page 2 ConocaPhillips Alaska, Inc. KRU 2A-05 ~ 2A-05 API: 501032003000 Well T : PROD An le TS: 48 d 8693 sssv SSSY Type: TRDP Orig Com etion: 5/16/1984 Angle @ TD: 48 deg ~ 9185 (is3i-is3z, OD:3.500) Annular Fluid: Last W/O: Rev Reason: Correct CV date Chan e Reference Lo Ref Lo Date: Last U date: 224/2005 Last Ta : 8840 TD: 9185 ftKB 11161NG (o-a7s~, OD:3.500, Last Ta Date: 9 3/4/2004 Max Hole Afl le: 57 d 7200 e9 ~ iD:zssz) ~ Casin Strin -ALL STRI NGS ^ I Descri lion Size To Bottom ND Wt Grade Thread SUR. CASING 9.625 0 3209 2619 36.00 J-55 ' PROD. CASING 7.000 0 9060 6152 26.00 J-55 CONDUCTOR 16.000 0 104 104 62.50 H-40 Tubin Strin -TUBING Corkscrewed T GLM #3• Used knuckled 1.5" Tool Strin Size To Bottom ND Wt Grade Thread 3.500 0 8791 5971 9.30 J-55 8RD EUE ABM Perforations Summer Interval ND Zone Status Ft SPF Date T Comment 8692 - 8730 5905 - 5930 C-4,UNIT B 38 12 628/1984 APERF 120 deg ph; 5.5" Csg Gun 8762 - 8764 5951 - 5953 A-4 2 4 628/1984 APERF 90 d h• 4' C Gun 8764 - 8776 5953 - 5981 A~ 12 8 6/8/1988 EPER Zero deg. phasing; Gearhard EJ II i 8776 - 8784 5961 - 5966 A~ 8 4 6/28/1984 APERF 90 d h• 4" C Gun 8796 - 8798 5974 - 5975 A-3 2 4 6/28/1984 RPERF 90 de h• 4" C Gun 8798 - 8834 5975 - 5999 A-3 36 8 6/8/1988 EPER Zero deg. phasing; Gearhard EJ II © I 8834 - 8855 5999 - 6014 A-3 21 4 6/28/1984 RPERF 90 d h• 4' C Gun Gas Lift M andrelsNalves St MD ND Man Man Type Mfr V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 8511 5787 MMH FMHO DMY 1.0 BK 0.000 0 72/1999 Production Ma ndrels/Va lves ~ St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 2 8607 5849 MMH FMHO CV 1.0 Broken 0.000 0 72/1999 3 8675 5893 MMH FMHO CV 1.0 BK 0.000 0 3/52004 Other lu s ui .etc. -JEWELRY De th ND T Descri lion ID 1931 1784 SSSV Baker'FVL' Locked0ut9/29/92 2.813 8555 5815 PBR Baker 3.000 Pert 8568 5823 PKR Baker'FHL' 3.000 (a7sz-s7aa) 8781 5964 PKR Baker'FB-1' 4.000 8789 5969 NIP Camco'D' Ni le NO GO 2.750 8790 5970 SOS Baker 2.992 8791 5971 TTL 2.992 Fish - FISH De th Descri lion Comment 8907 1' GLV FELL TO RATHOLE General Notes Date Note 6/3/1999 Well has serious scale roblems. 1/22200 CORKSCREWED TUBING STARTING 8659' WLM sos 879P8791 ~ 8/31200 WAIVERED WELL: IA x OA COMMUNICATION ( , OD:3.500) Perf (87968855) Pert (87968834) ~ ~ WELL LOG ~~ S , TRANSM/TTAL --r-~ - - ProActive Diagnostic Services, Inc. To: ABC Christine Mahnken 333 West 7tfi Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hale/Open Hole/Mechanical Logs and /or Tubing Inspectaon(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledc~ receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fay (907) 245-8952 1) Caliper Report 2) 16,Jut-08 2A-05 1 Report / EDE 50-103-20030.00 S~N~® J U L 2 ~ 2008 U7 C c~~1-a~~ y Signed Print Name: ('iVl.~~}~.,v, /la~,f .~ ~~~5~ Date _ _ . PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)Z45-8951 FAX: (907)245$8952 E-MAIL ~'~ ~ --- - J- , _~ -.. ~ _ ~~ WEBSITE an r~ - _ _ ~~~`~ C:\Documents and Settings\Owner\DesktoplTrmvsmit_Conow.doc • • Memory Multi-Finger Caliper ,~ Leg Results Summary. Company: ConocoPhillips Alaska, Inc. WeH: 2A-05 Log Date: July 16, 2008 Field: Kuparuk Log No.: 8697 State: Alaska Run No.: 2 API No.: 50-103-20030-00 Pipet Desc.: 7" 26 Ib. J-55 Top Log Inivl1.: Surtace Pipet Use: Production Casing Bot. Log Intv11.: 8,490 Ft. (MDR Inspection Type : Mechanical Damage /Restriction /nspection COMMENTS This caliper data is tied into the Casing Hanger @ 0' (AID). This log was run to assess the condition of the production casing logged with respect to mechanical damage and minimum LD. restrictions. The caliper recordings indicate bucMing throughout the majorRy of the production casing logged. Severe bends in joint 5 (190') and jant 6 (230') restrict the minimum I.D. to 5.61" and 5.09" respectively. A 3-D log plot of these severe bends is included in this report. Deposits are recorded from _6,000' to 8,490'. A graph illustrating minimum recorded diameters on a joint-by joint basis is included in this report. This is the second time a PDS caliper has been run on this well and the first time the 7" production casing has been logged. The caliper recordings indicate the 7" production casing logged appears to be in good tv fair condition with respect to corrosive damage, with a maximum recorded penetration of 28% in joint 153 (5,89T). The damage appears in the form of isolated pitting. No significant areas of cross-sectional wall loss (> 4%} are recorded throughout the production casing logged. ~ MAXIMUM RECORDED WALL PENETRATIONS Isolated pitting (28%) Jt. 153 ~ 5,897 Ft. (MD) Isolated pitting (27°~) Jt. 160 @ 6,162 Ft. (MD) Isolated pitting (23°!0) Jt. 156 ~ 6,023 Ft. (MD) Isolated pitting (20°~) Jt. 157 ~ 6,057 Ft. (MD) ' No other significant wall penetrations (> 17%) are recorded throughout the production casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the production casing logged. ' MAXIMUM RECORDED ID RESTRICTIONS Severe Bend Minimum I.D. = 5.09" Jt. 6 ~ 230 Ft. (MD} Severe Bend Minimum I.D. = 5.61" Jt. 5 C~ 190 Ft. (MD) Deposits Minimum LD. = 5.63" Jt. 219 ~ 8,489 Ft. (MD) ' Lt. Deposits Minimum I.D. = 6.03" Jt. 200 C~ 7,760 Ft (MD) Lt. Deposits Minimum I.D. = 6.07" Jt. 212 ~ 8,219 Ft. (MD) Field Engineer: K. Miller Analyst: C. Waldrop Witness: R. Dolcater ProActve Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog. com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 l ZS~~~~ ~ (~oC~s~ U~ • • PDS Multifinger Caliper 3D Log Plot ~~- Inc. Field : Ku aruk Company : ConocoPh~llips Alaska, P Well : 2A-05 Date : July 16, 2008 Description : Detail of Caliper Recordings Across Interval of Severe Bending • ~~ Minimum Diameter Profile Well: 2A-05 Survey Date: July 16, 2008 Field: Kuparuk Tool: MFC 40 No. 30807 Company: ConocoPhillips Ahaska, Inc. Tod Size: 2.75 inches Country: USA Tubing I.D.: 6.276 inches Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 Correlation of Recorded Damag f Pipe 1 7. in (1.6' -8453.4') Well: Fiefd: Company: Country: Survey Date: • ;e to Borehole Profile 2A-05 Kuparuk ConocoPhiilips Alaska, Inc. USA July 16, 2008 . Ap prox. T ool De viation ^ Ap prox. B orehd e Profil e 1 5 25 931 50 1907 75 2867 100 3834 ~ -~ v .n ..: LL E c ~ 125 ~ 4806 ~o ~ 150 5774 175 6749 200 7723 219 8453 0 50 100 Da mage P rofile ( % wall) /Tool Deviatio n (deg rees) Bottom of Survey = 219 • PDS Report Overview ~~~ -- ~`_~. Body Region Analysis Wetl: 2A-05 Survey Date: July 16, 2008 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Nom. Upset Upper 7 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetraron body :;.~~~ metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 220 pene. 5 202 10 3 0 0 loss 152 68 0 0 0 0 Damage Configuration (body ) 20 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 11 10 1 0 0 0 Damage Profile (% wall) ~ penetration body _t;,;, metal loss body 0 50 100 0 50 100 150 200 Bottom of Survey = 219 Analysis Overview page 2 • PDS REPORT JOINT TABS Pipe: 7. in 26.0 ppf )-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ELATION SHEET 2A-05 Kuparuk ConocoPhillips Alaska, Inc. USA )uly 16, 2008 Joint No. )t. Depth (Ft.) I'~~n. i_ ll:,~c, t (ln l Pen. Body (Ins.) Pen. % ~1ct,d I us <~ Min. LO• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 2 U 0.01 4 I 6.17 P 5 u 0.01 3 I 6.1 2 5 i) 0.01 3 I 6.1 3 80 ~? 0. 3 t3 I 6.15 4 118 U 0.01 2 I 6.17 5 158 U 0. 1 ~ 5.61 Severe end. 6 195 t) 0.01 Z 5.09 ev end. 7 234 (~ 0.03 i I 6.21 8 7 U 0.01 I 6. 4 313 c~ 0.01 t i 6.26 10 352 c) 0.00 1 I 6. 5 11 389 O 0.01 ~ I 6.26 1 42 6 ~ 0.01 ~' I 6.2 6 1 46 (I 1 I .24 4 503 U 0.01 3 1 6.25 15 43 U 0.01 ~ I 625 16 579 t) 0.01 t I 6.25 17 619 t) 0.01 i I 6. 6 18 658 U 0.01 ~ I 6. 5 698 0 .01 3 I 6. 20 36 ~) 0.01 3 I 6.24 21 776 U 0.01 Z I 6.25 2 816 ~? 0.01 2 I 6.24 23 854 ~ 0.01 2 1 6. 5 89 O 01 2 I 6. 5 25 931 0 0.01 3 I 6.23 26 971 it 0.01 2 I .24 27 1010 n 0.01 3 I 6. 8 1 49 II 0. 1 3 I 6.25 29 1089 U 0.0 3 I 6.25 1 7 U 3 I 4 31 116 (~ .0 Z I 6.22 Sli htBucklin t~ 0. 1 3 33 1244 a 0.01 I 6.25 U 1 i I .2 35 1324 t~ .01 ! I 6.2 Sli htBuc (in U ~ I 37 1401 i) 0.01 3 I 6 24 8 1 O I 4 39 148 U 0.01 2 I .21 Sli t o klin ~~ 0 ' I 41 1560 U 0.01 Z I 6.24 5 ! ~ ( I 6. 3 4 1637 U 0.0 3 I 6 1 Sli ht B cklin 7 n 4 I 6 45 1717 (~ 0.01 3 6.16 17 i) ~ I .1 S' 47 179 n 0.01 2 I 6.23 30 1 3 49 1867 0.0 1 6.24 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOI NT TABU Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: IATION SHEET 2A-05 Kupa ru k ConocoPhillips Alaska, Inc USA July 16, 2008 Joint No. )t. Deptfi (Ft) I'r~n. Ul~sc~t (Ins.) Pen. Body (Ins.) Pen. % Metal I oss °'~, Min. LD. (Ins.) Comments Darnage Profile (% wall) 0 50 100 50 1907 I~ 001 ~ 1 6.23 51 19 r 1 0.01 .3 I 6.22 52 1981 II 0.01 '' I 6.23 53 2020 ~ 1 0.01 ~ I 6.23 54 2057 ~~ 0.01 _' I 6.21 55 2096 ~? 0.01 i 6.2 56 2135 ~~ 0.01 ~ 6.23 57 21 4 U 0.01 I 6.2 58 2212 li 0.01 ~~ I 6.23 59 2250 it 0.01 ~' I 6.23 60 2288 a 0.01 ~ I 6.24 61 2326 t~ 0.01 ? I 6.25 62 2366 U 0.01 i t 6.24 63 2402 a 0.01 i 1 6.1 64 2440 c~ 0.01 4 1 6.23 65 2478 U 0.01 I 6.24 66 2518 I~ 0.01 l I 6.21 67 2558 ~~ 0.00 1 I 6.22 68 2596 I) 0.01 3 1 6.22 69 2636 O 0.01 ~ 1 .23 70 26 5 ~ ~ 0.0 - 1 6.18 71 271 II 0.01 ~; 1 6.2 72 2752 a 0.01 ~ i 6.23 73 2790 t) 0.01 ~ I 6.22 74 2828 Il 0.01 I 6. 75 2867 U 0.01 Z I 6.23 6 2905 U 0.01 2 4 5.93 77 2944 0 0.01 2 1 6. 3 Bucklin 78 2984 U 0.02 I 6.23 79 3023 U 0.01 3 1 6.23 B c lin 80 6 t~ 0 4 I 6. 81 3100 tl 0.01 Z .' 6.21 Bu klin 31 ~ 1 01 3 ' 83 3177 a 0.01 3 _' 6.22 3 5 u .0 ~ 1 Bu 'n 5 32 3 c l 0.0 i I 6.22 86 D ~ ~ 0. 1 ~' 1 6. 1 87 333 a 0.01 2 it 6.2'3 3 7 u 001 6 89 34 4 u 0.01 > I 6.23 0 ~~ 1 1 6 91 484 !~ 0.01 3 I 6.23 3 ~ ~ .01 3 1 0 93 3560 ~ ~ 0.00 1 I 6.21 0 U ' I 95 36 8 U 0.01 2 1 6.22 6 6 7 U .01 ~ I 6.1 97 3716 a 0.01 i I 6.21 3 U ' -' 99 3794 ~~ 0.01 3 I 6.21 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 7. in 26.0 ppf )-55 Well: 2A-05 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConowPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: July 16, 2008 Joint No. Jt. Depth (Ft.) I'c•n. I11,~•I (Im.) Pen. Body (Ins.) Pcn. °~~> Mc~l,~l Lu>~ ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 10 3834 t ~ 0.0 i 6.20 Bucklin 101 3873 U 0.01 _' 6.21 10 3910 a 0.01 ~ 1 6.21 103 3950 t ~ 0.0 ? I 6.21 Bucklin 104 39 9 t) 0. 3 6.20 105 4029 a 0.01 > I .20 106 4068 U 0.01 ~' I 6.17 107 4106 a 0.01 1 3 108 4146 U 0.01 I 3 1 9 4185 ti 0.01 3 6.17 10 42 5 t) 0.01 2 I 6. 3 B ck'n 111 4265 t~ 0.01 > I 6.23 112 43 4 t) 0.01 ~ 6. 2 13 4341 U 0.01 ~' 6. 1 Buckli 114 4378 a 0.01 ~' I 6. 11 4416 a 0.01 i I 6.14 1 6 4455 t) .O1 1 6. 2 ucklin 117 449 i t 0.04 1 U I 2 118 453 i ~ 0.01 2 I 6.23 119 4572 tl 0.01 1 .23 1 0 4611 t~ 001 4 I 6.2 121 4651 t~ 0.01 1 6.22 122 4691 t) 0.01 3 I 6.2 Bucklin 12 4730 U .01 > I 6.23 4 t) .01 4 I 6. 12 4806 c~ 0.01 I 6.23 Bu kli 126 44 a 0.01 2 I 6.24 127 4883 ~) 0.01 3 .21 128 4923 U 0.01 ) I 6.21 uc lin 1 9 496 U 0. 4 1 U _' 6.20 0 t) 00 1 131 50 t~ 0.01 ~ I 6.21 ucklin 3 5 U I 1 6. 133 5116 U 0.01 ~ I 6.19 U - 1 135 5192 U 0. 3 9 I 6. t) 0. 17 6 d 137 5269 ~) 0.04 1(1 6.18 1 30 a ~ 9 139 5346 t) 0.01 _' I 6.22 Buc lin 4 ) 05 1~ 1 141 5425 l) 0.03 8 I 6.23 0. 4 1) I 143 5504 t? 0.01 2 _' 6. 0 144 4 U 0 1 3 1 145 5 7 t~ 0.01 2 I 6.21 B c lin 4 6 t~ i I 47 56 6 t ~ 0.03 I 22 14 ~! 00 ~ I 4 5734 0.04 ! .1 _ Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf J-55 Well: 2A-05 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: July 16, 2008 --- - --- Joint Jt. Depth Pc•n. Pen. Pen. Metal Min. Damage Profile No. (Ft.) ~ Il~set Body % Loss LD• Comments (%wall) (Ins.) (Ins.) °-~> (Ins.) 0 50 100 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINTTABUTATION SHEET Pipe: 7. in 26.0 ppf J-55 Well: 2A-05 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal i.D.: 6.276 in Country: USA Survey Date: July 16, 2008 Joint No. Jt. Depth (Ft.) Nc~n. i Ih,E~t (In~.l Pen. Body (Ins.) Nc~n. .~~ `1c~t,rl I c,~s ~~ Min. LD• (tns.) Comments Damage Profile (%wall) 0 50 100 20 77 tl 0.02 ~~ i 6.03 Bucklin Lt. De sits. O1 776 ~) 0.03 .13 Lt. De its. 0 7799 l~ 0.0 t; 6.17 Lt De o its. 03 9 tl 0.01 4 _' 6.13 Lt. De osits. 204 7878 t) 0.01 6.18 Bucklin 20 7 18 t> 0.03 H 6.14 t. De sits. 06 7956 ~ ~ 0.02 ~ 6.14 t. De sits. 207 799 ti 0.01 i 6.10 Lt. De its. 208 80 2 c~ 0.02 (, 6.17 ucklin 09 8069 t) .03 F3 1 6.15 Lt. De sits. 210 8109 t~ 0.01 3 1 6.19 211 8146 U 0.0 b 6.16 t. a sits. 212 8183 U 0.0 I U _' 6.07 Bucklin Lt. De sits. 13 8223 u.tt-1 0.03 ~~ ? 6.09 L . De its. 14 8262 t~ 0.02 6.13 t. De its. 215 8300 c~ 0.01 2 Bucklin t. D sits 16 8340 a 0.03 ~) 6.15 17 37 O.U_s .01 3 ~' 6.1 t o 'ts. hallo 'ttin 18 8415 t~ 0.01 4 ~ 6.1 Bucklin Lt. a s'ts. 19 8453 t ~ 0. 5 ! 5.63 Corrosion De sits. Penetration Body Metal Loss Body Page 5 ~w ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ t~ -- .`~ PDS Report Cross Sections Well: 2A-05 Survey Date: July 16, 2008 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA N'o. of Fingers: 40 Tubin 7 ins 26 f -55 Anal t: C. Waldro Cross Section for Joint 153 at depth 5896.876 ft Tool speed = 68 ~ Nominal ID = 6.276 i Nominal OD = 7.000 ~ Remaining wall area = 99 Tool deviation = 58 ° Finger 2 Penetration = 0.083 ins Isolated pitting 0.10 ins = 28% Wa11 Penetration HIGH SIDE = UP • I • Cross Sections page 1 ~w ~ ~ r ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ w ~ PDS Report Cross Sections ,_ ~ ~. _ Well: 2A-05 Survey Date: July 16, 2008 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f -55 Anal st: C. Waldro Cross Section for Joint 160 at depth 6161.903 ft Tool speed = 71 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 99 Tool deviation = 61 ° Finger 15 Penetration = 0.077 ins Isolated pitting 0.10 ins = 27% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 PDS Report Cross Sections _ ~~ Well: 2A-05 Survey Date: July 16, 2008 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f -55 Anal st: C. Waldro Cross Section for Joint 6 at depth 230.27 ft Tool speed = 65 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 100 Tool deviation = 1 ° Finger 34 Projection = -0.766 ins Ovality due to Severe Bending Minimum I.D. = 5.09 ins HIGH SIDE = UP • Cross Sections page 3 - ~~. PDS Report Cross Sections t - Well: 2A-05 Survey Date: July 16, 2008 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f -55 Anal st: C. Waldro Cross Section for Joint 5 at depth 190.207 ft Tool speed = 70 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 100 Tool deviation = 2 ° Finger 16 Projection = -0.496 ins Ovality due to Severe Bending Minimum I.D. = 5.61 ins HIGH SIDE = UP • • Cross Sections page 4 KRU 2A-05 ConocoPhillips Alaska, Inc. 2A-05 API: 5010 3000 We I T PR D An le TS: 48 8693 sssv SSSV Type: TRDP Orig Com don: 5/16/1984 Angle ~ TD: 48 deg ~ 9185 (1931-1932, OD:3.500) Annular Fluid: Last WlO: Rev Reason: Correct CV date than R rents L Ref Date: L at U te: 4/2005 Last Te : 8840 TD: 9185 ftKB NBING (as791, OD:3.50D, Last Tag Date: 3/4/2004 Mex Hole 57 deg ~ 7200 '°:2ssz) _ Casin Strin -ALL STRI NGS ^ ~ De ri don Si e T Bottom TVD Wt G de Thread SUR. CASING 9.62 0 3209 2619 36.00 J-55 ' PROD. CASING 7.000 0 9060 6152 26.00 J-55 CONDUCTOR 16.000 0 104 104 62.50 H-40 Tubin Strin -TUBING Corkscrewed T GLM #3• Used knuckled 1.5" Tool 3trin Size To Bottom ND Wt Grade Thread 3 500 0 8791 597 9.30 J-55 8RD EUE AB Pertorations Summa Interval ND Zona Ste s Ft SPF Date T Comment ' 8692 - 8730 5905 - 5930 C-4,UNIT B 38 12 8/28/1984 APERF 120 deg ph; 5.5' Csg Gun ~ 8782 - 8784 5951 - 5953 A-4 2 4 8/28/1884 APERF 90 d • 4" C Gun 8784 - 8778 5953 - 5981 A-4 12 8 6/8/1888 EPER Zero deg. phasing; G rhard EJ II 8776 - 8784 596i - 5966 A~ 8 4 6/28/1984 APERF 90 d h• 4' C Gun 8796 - 8798 5974 - 5975 A-3 2 4 8/28/1984 RPERF 90 d h• 4' C Gu 8798 - 8834 5975 - 5999 A-3 36 8 6/8/1988 EPER Zero deg. phasing; Gearherd EJ II © I 8834 - 8855 5898 - 8014 A-3 21 4 6/28/1984 RPERF 90 •4' C Gun _ s Lift M andr elsNalves St MD ND Men Man Type Mfr V Mfr V Type V OD Latch Port TRO Dete Run Vlv Cmnt 1 8511 5787 MMH FMHO DMY 1.0 BK 0.000 0 7/2/1999 Production Ma ndrelsNalves St MD TVD Men Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 2 8607 5849 MMH FMHO CV 1.0 Broken 0.000 0 72/1999 3 8675 5893 MMH FMHO CV 1.0 BK 0.000 3/5/2004 Other lu s ui .etc. -JEWELRY De th TVD T Descri don ID 1931 1784 SSSV Beker'FVL' Locked Out 929/92 2.813 8555 5815 PBR Baker 3. 0 Pert 8568 5823 PKR B ker'FH ' 3.000 (a7sz-a7aa) 8781 5964 PKR Beker'FB-1' 4.000 8789 5969 NIP Camco 'D' Ni le NO GO 2.750 8780 5970 SOS Baker .992 8791 5971 TTL 2.992 Fish - FISH De th D i •on Comment 8907 1' GLV FELL TO RATHOLE General Notes Date Note 6/3/1999 Well has serious scale roblems. 1/ 20 CORKS REWE TU NG STARTING 8659' WLM sas 8790.879 ~ 8/31 0 WAIVERED WELL• IA x O COMMUNICATIO ( 1, OD:3.500) PeA (8796-8855) Pert (879&-8834) ~ ~ 1/~fELE LEl6 TRANSM/TTAL __ _~~3~ I ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~~ ~,~~ ~, ~ Z~~ Suite C Anchorage, AK 99518 Fax (907j 245-$952 1) Caliper Report 31-Mar08 2A-05 1 Report / EDE 50-103-20030-00 2) Signed : (@~~/(/ Date Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (90712458952 E-MAIL: ~'''.9a ~.;~?~a, ~-"~''~'f C+,~_';`.'3 WEBSITE •i'/:'J`:d,., ..eas'>~1~3.3.~.:v3'"'J C:\Documents and Settings\Owner\Desktop\Tsansmit_Conoco.doc i~ IJ J • • Memory Muft~Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Welt: 2A-05 Log Date: March 31, 2008 Field: Kuparuk Log No.: 9535 State: Alaska Run No.: 1 API No.: 50-103-20030-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 8RD EUE ABM Top Lag Iritvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 8,603 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection ' COMMENTS: This caliper data fs tied into the Baker'pHL' Packer @ 8,568' (Driller's Depth). ' This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the majority of the 3.5" tubing logged is in good condition. Isolated Pitting is recorded in Joint 157 (5,031') with a wall penetration of 38% and joint 98 (3,167') with a wall penetration of ' 29%. No significant areas ofcross-sectional wall loss (> 7%) are recorded throughout the interval togged. Caliper recardings indicate corkscrewed tubing thraughout the interval logged, and the i.D. is restricted to 2.70" in joint 7 due to severe buckling. ' MAXIMUM-REC~tDED WALL PENETRATIONS: Isolated Pitting (38%) Jt. 157 ~ 5,031 Ft. (MD) Isolated Pitting (29°~) Jt. 98 ~ 3,i67 Ft. (MD) ' No other significant wall penetrations (> 11 °~) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant wall penetrations {> 7%) are recorded throughout the interval logged, MAXIMUM RECORDED ID RESTRICTIONS Ovality due to Severe Buckling Minimum LD. = 2.70" Jt. 7 ~ 2S7 Ft. (MD) No other significant L D. restrictions are recorded throughout the interval logged. ~~~~ APR ~. ~. 200 Field Engineer. S. Carpenter Analyst: HY. Yang Witness: C. Fitzpatrick ProActive Diagnostic Serviced, Inc. J P.{~. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (20.9' -8601.5') Well: 2A-05 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: March 31, 2008 ^ A pprox. Tool De viation . A pprox. Borehol e Profil e 25 810 1600 2418 3208 3998 ~ c t 4787 0 5576 6365 7154 7943 GLM 1 GLM 2 269.1 8601 0 5 0 1 00 Da mage Pr ofile (% wall) / Tod D eviatio n (degr ees) Bottom of Survey = 269.1 1 u 25 50 . 75 100 - ~ 125 E Z _0 150 175 200 225 250 • • PDS Report Overview ~ S. Body Region Analysis Well: 2A-05 Survey Date: March 31, 2008 field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 8RD EUE ABM 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°k wall) ~ penetration body metal loss body 300 250 200 _ 150 100 50 0 0 to 1 to 10 to 20 to 40 ro over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 276 pene. 2 268 4 2 0 0 loss 78 198 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 3 3 0 0 0 0 Damage Profile (°k wall) t~ penetration body ~~a metal loss body 0 50 100 n GLM 2 Bottom of Survey = 269.1 Analysis Overview page 2 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 8RD EUE ABM Well: 2A-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiBips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 31, 2008 Joint No. Jt. Depth (Ft.) I't~n. lllsE~t (Ins.) Pen. Body (Ins.) Pen. °i~, ~1c~t,al Irxs ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 21 O 0.02 £~ 2.90 PUP 1 25 U 0.01 5 a 2.93 1.1 71 n 0.00 I ~) 2.89 P P 1.2 76 ~~ 0.01 -l 2.94 PUP 2 84 ~) 0.02 ti .96 3 116 ~) 0.02 £t ~, 2.95 4 148 U 0.02 2.97 5 180 I) 0.02 £~ 1 2.96 6 211 U 0.02 £3 4 2.74 Ova .Severe bucklin 7 243 ~) 0.02 £i ~' 2.70 val. Severe bucklin 8 275 t) .02 ti 2.94 9 306 ~) 0.02 ti ~ ~ 2.95 10 338 ~? 0.02 7 1 .96 11 369 a 0.02 8 ~ .96 12 400 l) 0.01 5 1 2.95 13 32 ~) 0.02 ti 3 2.97 14 464 ~) 0.0 8 2.96 15 495 O 0.02 £f z .96 16 527 O 0.02 £3 ~' 2.97 17 558 ~ ~ 0.02 8 ? 2.96 18 589 ~) 0.02 ..' 2.97 19 621 ~) 0.0 2.96 20 652 a 0.0 ~ 2.96 21 684 a 0.02 £3 2.98 2 715 U 0.01 4 I 2.93 23 747 a 0.01 3 ~~ 2.92 24 77 a 0.02 £i _' 2.96 25 810 ~) 0.01 b Z 2.96 26 842 U 0.02 £i 1 296 27 873 ~~ 0.02 £3 1 2.96 28 905 I) 0.02 7 I 2.93 29 936 c) 0.02 t3 4 2.98 30 968 O 0.02 7 5 2.96 31 999 U 0.01 E~ :.' 2.95 32 1031 U 0.02 £3 ~' 2.92 33 1062 ~~ 0.02 ~ 2.93 34 1094 t) 0.01 5 2.91 35 1125 ~) 0.02 t3 I 2.95 36 1157 ~) 0.02 £3 I 2.91 37 1189 a 0.01 5 c) 2.91 38 1220 U 0.01 i 2.96 39 1252 t) 0.02 ~ 2.96 40 1283 U 0.02 £3 _' 2.95 41 1315 U 0.0 7 I 2.93 42 1347 )) 0.02 E3 1 2.95 43 1378 U 0.02 7 I 2.96 44 1410 ~) 0.02 £~ ~ .96 45 1442 ~ ~ 0.02 7 ~ 2.96 46 1473 ~ ? 0.02 7 ~ 2.96 47 1505 0.01 (~ ? 2.97 Penetration Body Metal Loss Body Page 1 • . PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE ABM Well: 2A-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiiips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 31, 2008 Joint No. Jt. Depth (Ft.) I't~n. llt~set (Ins.) Pen. Body (Ins.) Pc~n. % ~Ic~Grl Loss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1537 ~) 0.01 2 ~' 2.96 49 1568 ~) 0.01 -1 i ~ 2.96 50 1600 U 0.0 > r ~ 2.93 51 1632 U 0.02 ti 2.95 52 1663 U 0.01 2 .96 53 1695 U 0.02 8 1 2.97 54 172 7 ~) 0.0 t3 I 2.96 55 1759 U 0.02 ~) I 2.97 56 1791 r t 0.02 ~ 2.98 57 1822 ~) 0.01 2 _' .95 58 1854 (t 0.02 Fi I 2.93 59 1885 t) 0.01 6 I .95 59.1 1917 I) 0.00 1 I 2.89 PUP 59.2 1923 U 0 U r~ .81 aker'FVL' SSSV 59.3 1936 ct 0.03 lu s 2.88 PUP 60 1941 ~ t 0.01 ~ _' 2.95 61 1972 U 0.02 H I .9 62 005 t~ 0.02 tt I 2.97 63 2036 t) 0.01 -1 2.97 64 2067 a 0.02 `~ _' 2.97 65 2099 U 0.01 ~ -t 2. 6 66 2130 tt 0.01 1 2.96 67 216 t 1 D.0 8 I 2.97 68 2194 t~ 0.02 t3 ~ 2.96 6 225 r~ 0. 2 ti 1 .9 70 2257 l1 0.01 i _' 2.96 71 2288 U 0.02 ti I 2.94 72 2320 a 0.02 ti _' 2.96 73 352 tt 0.01 E~ I 2.96 74 2385 U 0.02 t3 _' 2.94 7 2418 tt 0.02 t3 ' .97 76 2450 tt 0.02 7 1 2.97 77 2482 c1 0.02 7 2.95 78 2513 ~ 1 0.02 t; ~ 2.93 79 2545 i) 0.02 -1 .97 80 2576 a 0.01 4 _' 2.97 81 2608 It 0.02 £3 ~ .95 82 2640 a 0.01 4 (t 2.94 83 2671 U 0.01 4 u 2.97 84 2703 U 0.02 £t 4 2.96 85 2734 U 0.02 7 t) 2.93 86 2 765 I) 0.02 F3 ~' 2.94 7 2797 rt 0.02 7 ' .93 88 2829 ! t 0.02 ~ 2.95 89 2860 ~ t 0.01 4 2.96 90 2892 ~~ 0.02 2.96 91 2924 ~? 0.02 t3 2.96 92 2 955 t t 0.02 7 2.96 93 2987 ~! 0.01 ~ !~ 2.97 94 3018 ~ 0.03 1I -l 296 _ Penetration Body Metal Loss Body Page 2 ~ ~ PDS REPORT JOINT TABUTATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE ABM Well: 2A-05 Body Wall: 0.254 in Field: Kuparuk Upset WaN: 0.254 in Company: ConocoPhi6ips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 31, 2008 Joint No. Jt. Depth (Ft.) I't~n. Ul,cc~t (Ins.} Pen. Body (Ins.) Pen. "/~, Metal Lo,s ",i> Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 95 3050 U 0.01 ~ ti 2.92 96 3081 U 0.0 q 2.95 97 3112 O 0.0 ti ~~ 2.96 8 3145 (~ 0.07 ~`) i 2.94 Isolated ittin 99 3177 ~1 0.02 £i 2.93 100 3208 l) 0.01 l 2.93 101 3240 ~) 0.01 (~ _ 2.96 10 3272 t) 0.0 tt -£ 2.95 103 3303 0 0.0 i 2. 5 104 3336 U 0.02 t3 ~ ~ 2.93 10 33 7 O 0.01 > -t 2.94 106 3399 U 0.02 .92 107 3430 U 0.01 ~' _' 2.95 108 346 0 0.02 ti ~' 2.94 109 3493 U 0.02 ~~ ~~ 2.96 110 3524 O 0.02 t3 2.95 111 3555 O 0.02 `~ ~"~ 2.96 11 3587 U 0.0 £3 ~ .97 11 36 9 U 0.01 5 5 2.96 114 3651 U 0.0 8 _' 2.96 115 3682 U 0.02 £3 2.95 116 3715 U 0.02 £3 ~ 2.94 117 3746 U 0.01 ~£ I 2.96 118 3777 U 0.02 ti 1 2.95 119 380 0 0.0 (~ 93 120 3840 U 0.02 £3 _' 2.93 121 3872 U 0.01 (i Z 2.94 122 3904 (~ 0.02 ti 1 2.95 123 3934 a 0.02 t3 ; ~ 2.94 124 3966 O 0.01 ? _' 2.93 125 3998 U 0. 1 ~ .94 126 4028 a 0.02 £3 2.95 127 4060 tl 0.02 t3 I 2.96 128 4093 U 0.01 -3 _' 2.96 129 4123 O 0.02 £~ 2.94 130 4155 I? 0.01 4 ~' 2.96 131 4186 ~) 0.02 8 ~ 2.95 132 4219 U 0.01 6 ' 2.95 133 4250 t) 0.02 £3 _' 2.97 134 4282 U 0.02 t3 3 2.95 13 431 U 0.01 ri -l 2.95 136 4345 U 0.01 4 ~ 2.93 137 4377 ~) 0.0 c) 4 2.95 138 4408 U 0.02 £3 _' 2.95 139 4440 U 0.0 fj 295 140 4472 (~ 0.01 4 .I 2.96 141 4504 (~ 0.02 c) I 2.94 142 4534 U 0.02 £3 2.94 143 4566 U 0.02 8 -1 2.92 144 4598 U 0.01 4 2.95 Penetration Body Metal Loss Body Page 3 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 8RD EUE ABM Well: 2A-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: March 31, 2008 Joint No. Jt. Depth (Ft.) I'~~n. ULne~~ (Ins.) Pen. Body (Ins.) Pe,n. °ib ~t~~t,~l lugs °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4630 U 0.02 ~ Z 2.93 146 4661 U 0.02 8 ~ 2.94 147 4693 U 0.02 ~~ I 2.95 148 4724 O 0.02 ti _' 2.93 149 4756 ~ ~ 0.02 - _' .94 150 4787 i ~ 0.03 I U i> 2.95 151 4819 ~ ~ 0.02 ti ~ 2.95 152 4851 l ? 0.01 5 2.94 153 4882 U 0.0 f3 ! 2.95 154 4913 U 0.02 ti _' 2.94 155 4944 I' 0.01 4 -I 2.95 156 4976 ~ I 0.03 1 1 -I 2.92 157 5008 ~~ 0.10 3t3 2.94 Isolated ittin 158 5039 ~~ 0.02 ~) 1 2.92 159 5071 t i 0.02 t3 2.94 160 5103 a 0.01 4 2.95 61 5135 U 0.01 ~1 2.91 16 5166 U 0.01 6 2.93 163 5198 ~l 0.01 -I 2.93 164 5229 0 0.02 ti 2.94 165 5261 (~ 0.01 5 1 .94 166 5293 l1 0 02 t3 ~ 2.93 167 5324 ~) 0.02 8 ~ 2.93 168 5356 ~ ~ 0.01 4 ~ 2.94 169 3 7 ~! 8 I 2.94 170 5418 ~) 0.02 I 2.95 171 5450 l) 0. 2 ~ ~ _' 2.94 172 5481 t) 0.02 f3 ~ 2.94 173 5513 c) 0.01 ~ I 2.92 174 5545 U 0.02 t3 1 2.93 175 5576 t~ 0.02 8 1 2.95 176 5608 U 0.02 y 2 2.76 177 5639 0 0.02 t3 ~' 2.94 178 5671 11 0.01 2 _' 2.95 179 570 t) 0.02 ti _' 2.94 180 5734 ~ ~ 0.01 4 2.93 181 5765 ~ 1 0.02 7 I 2.90 182 5797 (t 0.02 8 2.94 183 5828 a 0.02 7 2.95 184 5861 U 0.02 8 ? 2.94 185 5892 ~ 1 0.01 5 I 2.95 186 5923 l~ 0.02 7 ~ 2.90 187 5955 U .02 7 _ 2.96 188 5987 a 0.02 t3 ~ 2.94 189 6019 l) 0 01 , t 2.93 190 6050 U 0.01 -1 I 2.94 191 6082 U .01 ~ _' 2.93 192 6114 U 0.01 4 ~ 2.94 193 6145 t1 0.02 `~ I 2.93 194 6176 ~ I 0.02 ti _' 2.92 __, Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 8RD EUE ABM Well: 2A-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 31, 2008 Joint No. Jt. Depth {Ft.) I'rn. III„c•t (li ~.1 Pen. Body (Ins.) Pc~n. `%, Mcc~t Loss "~> Min. LD• (Ins.) Comments Damage Profile (%waN) 0 50 100 195 6208 I ~ 0.02 ~3 t .93 196 6239 t 1 0.02 2.94 197 6270 ~~ 0.02 ti ~ 2.93 198 6302 I ~ 0.02 f~ .93 199 6333 ~ ~ 0.02 ~ _' .92 00 636 ~ ~ 0.01 (> 2.90 01 6398 ~! 0.02 t9 ~' 2.94 202 6428 U 0.01 5 _' 2.90 203 6460 U 0.01 ~ 2 2.93 204 6492 a 0.01 ' .94 205 6522 ~~ 0.02 t3 I 2.91 06 6554 l~ 0.02 ti 1 2.94 207 6586 11 0.02 ti i 2.92 208 6618 l) 0.02 £i I 2.94 209 6650 t ~ 0.01 5 I 2.93 210 6682 t1 0.02 t3 ! 2.95 211 6714 U 0.0 ti I .92 12 674 ~~ 0.02 t3 _' 2.89 213 6774 U 0.02 ~~ 1 2.94 214 6805 l~ 0.01 ~~ I 0 2 5 6838 ~~ 0.01 5 2.94 216 6870 ~ ~ 0. 1 6 2.91 17 6901 a 0.02 tt 1 2.90 218 6932 U 0.02 t3 1 2.92 219 6964 a 0.02 is 2.93 220 6996 c ~ 0.01 2 _' 2.92 221 7027 U 0.0 ,' I 2.93 222 7059 l1 0.01 4 2.93 2 7090 (t 0.01 d I .93 224 7122 t) 0.01 6 1 2.92 225 7154 l) 0 01 5 1 2.92 226 7185 O 0.01 5 1 2.91 227 7217 tl 0.01 5 1 2.93 228 7247 t) 0.02 9 i 2.91 2 9 7279 t) 0.02 ~ 5 2.92 230 7311 U 0.02 t3 ~' 2.92 231 7342 ~ ~ 0.03 12 5 2.93 232 7374 ~~ 0.02 i 3 2.94 233 7406 ~~ 0.02 t3 5 2.92 234 7438 t~ 0.02 9 _' 2.91 235 7469 a 0.01 6 3 2.93 236 7501 ~~ 0.01 2 _' 2.93 237 7533 t~ 0.02 9 ~' .92 238 7563 U 0.03 10 t ~ 2.88 39 7595 ~) 0.01 6 I 2.93 240 7627 ~~ 0.01 5 2.94 241 7658 ~ ~ 0.01 b 1 2.9 242 7689 ~~ 0.02 tt ~ 2.92 243 772 ~ ~ 0.02 r~ ~ 2. 2 244 7754 ! ~ 0.02 - 2.92 Penetration Body Metal Loss Body Page 5 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE ABM Well: 2A-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 31, 2008 Joint No. Jt. Depth (Ft.) I'i•n. l1)~sc•t (lns.) Pen. Body (Ins.) I'en. `% McU~I I o~c `~~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 245 7785 (~ 0.02 (~ 4 2.94 246 7817 l~ 0.01 5 3 2.92 247 7848 a 0.02 ti 2.92 248 7880 ~ ~ 0.01 5 ~. ~ 2.88 49 7913 U 0.0 ti ~ 2.91 250 7943 U 0.02 0 _' 2.92 1 7975 l) 0.01 4 l) 2 93 252 8007 U 0.01 5 ~ 2.94 253 8037 l) 0.01 6 2 2.93 254 806 ~) 0.02 ti Z 2.93 255 101 O 0.01 i I 2.91 256 8132 U 0.01 ~ 1 2.92 257 8163 U 0.0 t3 -1 2 93 58 8195 a 0.01 ~~ 1 2.93 259 8226 a 0.02 _' 2.81 260 8259 U 0.01 d 1 .90 261 8290 U 0.01 (~ .91 262 8321 U 0.01 ~ 2.93 263 8353 ~) 0. 1 5 i 2.94 264 8384 U 0.01 > 2.94 65 8417 ~ ~ 0.01 t> s 2.94 2 6 8448 U 0.02 t3 1 2.91 267 8480 U 0.01 5 U 2.91 267.1 8507 U 0.01 (~ _' 2.96 PUP 67.2 8511 t) 0 l) ~! N A GLM 1 atch ~ 6:30 267.3 8518 U 0.02 t3 1 2.91 PUP 268 8519 U 0.02 ti 3 2.93 268.1 8549 U 0 l) ~~ N A Polished Bore 268.2 8565 O 0 U u 3.00 Baker PBR 268.3 8568 ~~ 0 i ~ i ~ 3.00 Baker 'FHL' Packer 269 8575 0.03 ~9"3 - 269.1 8601 0 - ~ -~ _Aj'~\_ _ _ __ I'r<xiuction iVtandrel Penetration Body Metal Loss Body Page 6 ~~ _ y ~+~ PDS Report Cross Sections Well: 2,A-05 Survey Date: March 31, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: Conoco Phillips A-aska, Inc. Tool Size: 1.69 Country: USA ,~lo. of Fingers: 24 Tubin 3.5 ins 9.3 f -55 8RD EUE ABM Anal st: HY. Yan Cross Section for Joint 157 at depth 5030.79 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 51 ° Finger 2 Penetration = 0.096 ins Isolated pitting 0.10 ins. = 38°~6 Wall HIGH SIDE = UP • Cross Sections page 1 PDS Report Cross Sections Well: 2A-05 Survey Date: ~'Narch 31, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: Conoco Phillips Alaska, tnc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf I-55 SRD EUE ABM Analyst: HY. Yane Cross Section for Joint 98 at depth 3166.9 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 °~ Tool deviation = 47 ° Finger 1 Penetration = 0.074 ins Isolated pitting 0.07 ins. = 29°~ Wall HIGH SIDE = UP • • Cross Sections page 2 ~ ~ ~ ~ r ~^ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~ - ~-'~ „ 4 Well: 2A-05 Survey Date: March 31, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: l4 Tubing: 3.5 ins 9.3 ppf I-55 8RD EUE ABM Analyst: HY. Yang Cross Section for Joint 7 at depth 267.04 ft Tool speed = 43 Nominal tD = 2.992 Nominal OD = 3.500 Remaining wall area = 100 °~ Tool deviation = 0 ° Finger 15 Projection = -0.138 ins Ovality due to severe buckling Min. ID = 2.70 ins. HIGH SIDE = UP • • Cross Sections page 3 • 1.i..1 ConacoPhillips Alaska, Inc. KRU 2A-05 " 2A-05 API: 501032003000 Well T : PROD An le TS: 48 de 8693 sssv SSSV Type: TRDP Orig Com etion: 5!16/1984 Angle ~ TD: 48 deg ~ 9185 (1931-1932, OD:3.500) Annular Fluid: Last W/O: Rev Reason: Correct CV date chap e Reference L Ref L Da Lest U te: 224!2005 Last Ta : 8840 TD: 9185 fiKB TUBING (0-8791 OD:3.500, Last Tab Date: 3/4/2004 Max Hole Arl le' 57 deb ~ 7200 i~:zssz) ~ _ Casin Strip -ALL STRI NGS . J 'lion Size To Bottom TVD Wt Thread J SUR. CASING 9.625 0 3209 2619 36.00 J-55 ' PROD. CASING 7.000 0 9060 6152 26.00 J-55 CONDUCTOR 16.000 0 104 104 B2.50 H-40 Tubin Strip -TUBING Corkscrewed T GLM 4t3~ Used knuckled 1.5" Tool Strip Size To Bottom ND Wt Grade Thread 3.500 0 8791 5871 9.30 J-55 8RD EUE ABM Perforations Summa Interval ND Zone Status Ft SPF Dete T Comment 8692 - 8730 5805 - 5930 C-4,UNIT B 38 12 6/28!1984 APERF 120 day ph; 5.5" Csp Gun 8782 - 8764 5951 - 5953 A-4 2 4 8/28!1984 APERF 90 •4' C Gun 8764 - 8776 5953 - 5861 A-4 12 8 6/8/1988 EPER Zero dep. phasing; Gearhard EJ II ~ 8776 - 8784 5961 - 5986 Amt 8 4 628/1984 APERF 90 d h• 4' C Gun ~ 8796 - 8798 5974 - 5975 A-3 2 4 628/1984 RPERF 90 h• 4" C Gun i ~. 8798 - 8834 5975 - 5999 A-3 36 8 66/1988 EPER Zero deg. phasing; Gearh rd EJ II © I 8834 - 8855 5999 - 6014 A-3 21 4 6/28!1984 RPERF 90 d • 4" C Gun Gas Lift Man dr elsNalve s St MD ND Man Mfr Men Type V Mir V Type V OD Latch Port TRO Dete Run Viv Cmnt 1 8511 5787 MMH FMHO DMY 1.0 BK 0.000 0 72/1998 Production Ma ndrelsNa lves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 2 8607 5849 MMH FMHO CV 1.0 Broken 0.000 0 72/1999 3 8875 5883 MMH FMHO CV 1.0 BK 0.000 0 /2004 Other lu s ui a c. -JEWELRY De th ND T Descri lion ID 1931 1784 35SV Beker'FVL' Locked Out 9/29/92 2.813 8555 5815 PBR Baker 3. 0 Pe,1 8 68 5823 PKR Baker'FH ' 3. (a7sz-8784) 8781 5964 PKR Beker'FB-1' 4.000 8789 5969 NIP Camco 'D' N' b NO GO 2.7 8790 5970 SOS Baker 2.992 8791 5971 TTL 2.992 Fish - FISH D th i on C e t 8907 1" GLV FELL TO RATHOLE General Notes Date Note 6!3/1999 Well has serious scale oblems. 1/22 00 CORKSCREWED TUBING STARTING 659' WLM sas 8790.8791 . 8/31200 WAIVERED W L: IA x OA COMMUNICATION ( , OD:3.500) Pert (879G8855) Pert (8798-8834) 2A-OS (PTD 184-06?) Failed TIF~ . Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, March 10, 2008 2:51 PM ~ ~,~2~~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) `e~~ Cc: NSK Problem Well Supv Subject: 2A-05 (PTD 184-067) Failed TIFL Attachments: 2A-05 TIO.jpg; 2A-05 TIO.jpg Jim and Tom 2A-05 (PTD 184-067) Failed a waiver compliance TIFL esterday. Based on fluid levels, the top pa___ ck off_gas lift mandrel (POGLM) packer is suspected as the leak point. a well will remain shut in until either the POGLM packers can be replaced or until tubing integrity is restored with patches in place of the POGLM's. TI110 prior to the TIFL was 300/850/80. The well is currently carried on the master SCP report and will be added to the weekly report. A 3 month TIO plot and schematic ~ c ed Please let me know if you have any questions MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 «2A-05 TIO.jpg» «2A-05 TlO.jpg» 3/20/200$ KRU 2A-OS PTD 184-067 TlIi4 PI©t - 2A-05 1000 Boa on 600 a 400 200 - -= I ' 1 0 -I-~-~+ 10-Dec-07 23-Dec-07 05-Jan-08 18-Jan-08 31-Jan-00 ~ :~-r ea-u~ to-r eo-uu Date 200 150 a c 100 m Y 50 0 • • • ~.`~ ~~ ~ yf ' Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK-99501 ~~~ ~ ~~ ~,~~%' ~'~~~ Dear Mr. Maunder: • :-~ ~ ; , - ~- F:'. f ~ ... nL:.- G... ~~. ~ o-. . -~~7 ~g~ Enclosed. please find a spreadsheet with a~list of wells from the Kuparuk f eld {KRLT). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water -from entering the annular space.. As per previous agreement with the AOGCC; this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitor/sealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the. well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips We11 Integrity Projects Supervisor __ __ _ _ __ ___ _ __ • Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant 1"op-off Report of Sundry Operations (10-404) Date Kuparuk Field ~ ~r~ ~r~nm Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-01 184-057 SF na SF na 1.5 12/14/2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na 44" na 50 12/14/2007 2A-04 184-053 9'6" 1.2 10" 9/24/2007 3.5 12/14/2007 2A-05 1$4-067 SF rta SF na 5 12/512007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12/14/2007 2A-08 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.75 12/14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12/5/2007 2A-11 186-003- SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14!2007 2A-14 185-145 SF na SF na 3.5 12/14/2007 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18" 9/24/2007 3 12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5/2007 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 March 15, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action 2A-05 Variance (K-valve) If you have any questions, please call me at 263-4241. Sincerely, P. $. White Senior Engineer Kuparuk Petroleum Engineering Attachments FTR031595 (w/o atch) RECEIVED MAR 1 7 1994 Alaska Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242 2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program 2. Name of Operator 15. Type of Well: Development X ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 537' FSL, 53' FEL, SEC 14, T11N, R8E, UM At top of productive interval 1282' FSL, 1475' FWL, SEC 23, T11N, R8E, UM At effective depth 1102' FSL, 1410' FWL, SEC 23, T11N, R8E, UM At total depth 973' FSL, 1282' FWL, SEC 23, T11N, R8E, UM Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Operation Shutdown _ Re-enter suspended well_ Plugging _ Time extension _ Stimulate__ - Pull tubing _ Variance _ Perforate _.~ Other__ 6. Datum elevation (DF or KB) 12. 91 85' feet Plugs (measured) true vertical 6 2 3 5' feet NONE measured 8979' feet Junk (measured) true vertical 6 0 9 6' feet NONE Length Size Cemented 1 0 4' 1 6" 175 SX CS II 3209' 9 5/8" 1000SXPFE 130' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-05 9. Permit number 84-67 10. APl number sod 03-20030 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 104' 104' 250 SX CLASS G 31 1 0' 2 5 8 8' 9060' 7" 350 SX CLASS "G" 9060' 61 52' 250 SX PFC measured 8692'-8730', 8762'-8784', 8796'-8855' true vertical 5908'-5930', 5950'-5965', 5973'-61 03' Tubing (size, grade, and measured depth) ® E EIV D Packers and SSSV (type and measured depth) BAKER FHL PACKER@8530', BAKER FB-1 PACKER @ 8743', BAKER FVL SSSV @ 1893' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure reperforate A Sand 8764'-8776', 8798'-8834' MD JUL 2 199 Alaska .0Jj .& Gas Cons. Anchorage 14. Pressure Prior to well operation Subsequent to operation 15. Attachments Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing 279 792 0 5OO 324 819 0 500 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector __ Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed d'~L)" ~) Title Kuparuk ~' Petroleum Engineer Form 10-404 Rev 06/15/88 Service Date 2O0 200 SUBMIT IN DUPLICATE ~ARCO Alaska, Inc~~ Subsidiary of Atlantic Richfield Comp~ WELL CONTRACTOR REMARKS FIELD-DISTRICT-STATE OPERATION AT REPORT TIME com~}.c ! WELL SERVICE REPORT' 0'700 0~2,o 1o2o -d [o~w )qoo I~q.~ / W.Fo / ! 27g'-/ Anci~oreg~. ~.. [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO ~laska, Inc. Post Office B~,,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticioated Start Date 2A-05 Convert to Water Inj. September, 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering S. P. Hoolahan ATO-1226 KOE1.4-9 (w/o attachments) (w/o attachments) REcEIVE JUL ~0 ~,, Alaska Oil & Gas Cons. Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany .... ' STATE OF ALASKA '-- ~ OIL AND GAS CONSERVATION COMMI,.%'51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well _ Change approved program J~_ Operation Shutdown_ Re.enter suspended well_ Plugging _ Time extension_ Stimulate _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' / Development ~ Exploratory _ Stratigraphic ~ Service ~. ~ ~e~i~ 4. Location of well at surface 537' FSL, 53' FEL, Sec 14, T11N, R8E, UM At top of productive interval 1282' FSL, 1475' FWL, Sec 23, T11N, R8E, UM At effective depth 1102' FSL, 1410' FWL, Sec 23, T11N, R8E, UM At total depth 973' FSL, 1282' FWL, Sec 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 91 8 5 feet 6235 feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 130' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-05 9. Permit number 84-67 10. APl number 50-1o3-20o3o 11, Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measure true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8979 feet 6 0 9 6 feet Length Size 104' 1 6" 3209' 9 5/8" 906O' 7" Junk (measured) Cemented 175 Sx CS II 104' 1000 Sx Permafrost E & 250 Sx Class G 3 2 0 9' 350 Sx Class G 9 0 6 0' & 250 Sx PFC measured 8692'-8730' ,8762'-8784', 8796'-8855' true vertical 5908'-5930', 5950'-5965', 5973'-6103' Measured depth True vertical depth 104' Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 8791' Packers and SSSV (type and measured depth) Baker FHL Packer @ 8530', Baker FB-1 Packer @ 8743', Baker FVL SSSV @ 1893' 13. Attachments Description summary of proposal _ Detailed operation program _ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: September, 1992 Oil __ Gas m 16. If proposal was verbally approved Name of approver Date approved Service 2619' 6152' Alaska Oil & (~as Cons. ;Anchora9 BOP sketch Suspended WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C'{~. ~ Title Operations Engineer FOR COMMISSION USE ONLY Date 7/~-. 7/~ ~---- Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test ~. Subsequent form require 10- ~/Off Approved by order of the Commission Form 10-403 Rev 09/12/90 Commissioner IApproval No. ~,pproved Cop~ Returned Date <~'/..~ /~ SUBMIT IN'TRIPLICATE Well 2A-05 Conversion to WAG Injection ARCO Alaska requests approval to convert Well 2A-05 from an oil producer to a WAG injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water and gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 5908' and 6103'.~° This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. p, ECEIYE Alaska Oil & Gas Pnch0ra(j~ WELL 2A-05 PRODUCER APl # 501032003000 SURFACE LOCATION: 537' FSL, 53' FI:L, SEC. 14, T11N, R8E, UM TOP KUPARUK: 1282' FSL, 1475' FWL, SEC. 23, T11N, R8E, UM DEPTHS: REFERENCED TO 0' RKB ALL DEPTHS MD-RKB (RKB=33.57') WEll TYPE: PRODUCER ,I 16": 62.5# H-40 @ 104' 9.625": 36# J-55 @ 3209' BAKER PBR: BAKER FH PKR: @ 8517' @ 8530' C4 C3 BLAST JOINTS BAKER FB PKR: CAMCO D NIPPLE: 2.75" ID BAKER SHROUT: @ 8743' @ 8751' @ 8752' B A4 A3 7": 26# J-55 @ 9060' VOLUME: 0.0383 BBL/FT PBTD: 8979' SPUD' 05/06/84 COMPLETION' 06/28/84 L SSSV: BAKER FVL 2.812" ID @ 1893' GLMI' 8473' /1" McMurry/ DV GLM2: 8569' / 1" MACCO/DPHFCV GLM3: 8637'/ 1" MACCO/DPHFCV 8692'-8730' 12 SPF 3.5" 9.3# J-55, @ 8791' VOLUME: 0.00870 BBL/FT HOLE ANGLE ACROSS KUPARUK = 49 DEGREES MAX. HOLE ANGLE = 55 DEGREES @ 3900' VOLUME TO TOP PERF = 74 BBLS 8762'-8784' 4 SPF 8796'-8855' J U L 5 0 4 SPF /~,last(a 0il & Gas Co,Is. Anchora.ge LAST TAG DATE: 12/8/91 @ 8901' WL REVISION' 12/9/91 ARCO Alaska, Inc. Date: December 30, 1988 Transmittal #: 7392 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 Z- 1 4 Kuparuk Fluid Level Report 1 2 - 2 7- 8 8 Tubing 1 Y- 0 6 Kuparuk Fluid Level Report I 2 - 2 6 - 8 8 Casing 2A-05 Kuparuk Fluid Level Report 1 2-26-88 Tubing 2 X- 1 4 Kuparuk Fluid Level Report 1 2 - 2 5 - 8 8 Tubing 2Z- 1 3 Kupaurk Fluid Level Report 1 2- 2 6 - 8 8 Tubing 2 C- 0 9 Kuparuk Fluid Level Report 1 2 - 2 2 - 8 8 Casing 2 W - 0 1 Kuparuk Fluid Level Report 1 2 - 2 2 - 8 8 Casing 3 K - 0 6 Kuparuk Fluid Level Report 1 2 - 21 - 8 8 Casing 3 B - 1 3 Kuparuk Fluid Level Report I 2 - 2 1 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION.-_ ~ ~ ^~sl~.0l! ~._~as Cons. C0mmlss[on D&M State of Alaska . Unocal Chevron Mobil SAPC STATE OF ALASKA ALAS,., OIL AND GAS CONSERVATION COM,,..SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown , ] Re-enter suspended well -- Alter casing ['; Time extension Change approved program Plugging '? Stimulate .? Pull tubing Amend order [ Perforate/~ Other 2 Name of Operator ARCO Alaska: Inc. 3 Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 537' FSL, 53' FEL, Sec. At top of productive ~nterval 1282' FSL, 1475' FWL, Sec. 23, T11N At effective depth 1102' FSL, 1410' FWL, Sec. 23, T11N At total depth 973' FSL, 1282' FWL, Sec. 23, T11N 11. Present well condition summary 9185 Total depth: measured true vertical 6235 14, TllN, R8E, UM R8E, UM R8E, UM R8E, UM feet feet Plugs (measured) 5. Datum elevation (DF or KB) RKB 130' 6. Unit or Property name Kuparuk River Unit 7. Well number 2A-05 8. Permit number 84-67 9. APl number 50-- ]03-20030 lO. 'P°°~uparuk River Oil Effective depth: measured 8979 ' feet true vertical 6096' feet Junk(measured) feet Casing Length Structural Conductor 104' Surface 3209' Intermediate Production 9060 ' Liner Perforation depth: measured true vertical Pool Size Cemented Measured depth True Vertical depth 16" 175 Sx Cold Set II 104' 104' 9-5/8" 1000 Sx Permafrost E 250 Sx Class G 3209' 2619 7" 350 Sx Class "G" 9060' 6152' 250 Sx PFC 8692' -8730', 8762' -8784', 8796' -8855' MD RECEIVED 5908'-5930', 5950'-596fi', 5973'-6103' TVD Tubing (size, grade and measured depth) JUN 3-1/2", J-55, at 8791'. Alaska Oil & Gas Cons. Commlssi~ Packers and SSSV (type and measured depth) ' ~ Anchorage RakPr FH! Pack~r 0 RRRI3' RRk,:,r' FR 1 PackPr Fa R7Z].3' Ra~',:,r FVI ~qqV 0 1Rq~' 12.Attachments Description summ~ry of proposal/~ Detailed operations program [71 BOP sketch 13. Estimated date for commencing operation June 10, 1988 Date 14. If proposal was verbally approved '-~J~.~e~,Jc~i[ ?V'oi'~c ~e~oz'f:ec]. om Name of approver Z... J:,~ 4 f~'m 1~/0 ..... ~,ter.].__/._._/ Date approved 15. I hereby certify that the foregoing is true and correct to the~est of my knowledge __ Signed ,,,~dz~,.,¢4' ~ ~~~~TitIe~J'~ 0 _.4~.J-~ ~- " / 1...,~..,~.1. ~ Commission Use Only Notify commission so representative may witness I Approval No. i-:., Plug integrity [] BOP Test ~-, Location clearanceI O~ ' '~ '~ Conditions of approval ORIGINAl. SIGNED BY LONNIE C. SMITH ~,pproved Copy Returned., ,, Commissioner Approved by Form 10-403 Rev 12-1-85 by order of 6.~ the commission Date ,-~,~---~ Submit in triplicate~c// Kuparuk Well 2A-05 Well 2A-05 is a selective single producer with only the A Sand open at this time. Proposed is re-perforating sections of the A Sand to reduce the completion pressure drop and enhance rate. A copy of the proposed program to add the subject perforations is attached. All downhole work will be performed with electric line conveyed tools. ^ 5000 psig electric line BOP and lubricator will be employed during all downhole work. Static bottomhole pressures from wellhead pressure and fluid levels indicate a static BHP of 3150 psig in the A Sand, and 3130 psig in the C Sand. Messrs. Chambers and Jordan June 2, 1988 page 3 Procedure To Add A Sand Perforations Well 2A-05 1. MIRU electric line unit and mast truck. . GIH with 2 1/8" semi-expendable perforating gun w/CCL. Tie in to OTIS CCL/TCL dated 11/25/84. Avoid tagging bottom w/gun. PBTD tagged 5/28/88 at 8926'. . Flow well to system to allow a slight underbalance while perforating. Perforate the folowing intervals at 4 SPF, 0 degree phasing, magnetically decentralized: 8764' - 8776' 8798'-8834' Depths are RKB measurements. The following semi-expendable guns are suitable for this job: Schlumberger Enerjet II Dresser Silver jet Gearhart E-jet . RD electric line equipment and produce well to system. Obtain stabilized well test at earliest convenience. ARCO Alaska Inc. Is a subsidiary ot Atlantic Richfield Company AR3B-6001.A 3 ,ii 1. 5000 PSI ?" WELLHE.&D CONNECTOR FLANGE 2. 5000 PS1 WIRELINE RAJAS (VARIABLE · 3.5000 PSI 4 1/6" LUBRICATOR 4. 5000 PS1 4 1/6" FLOW TUBE PACK-OFF RECEIVED Alaska Oil & Gas Cons. CommissiOn Anchorage N ! REL I NE BOP EOU ! PH£NT STATE OF ALASKA ALA .... OIL AND GAS CONSERVATION CON. ...,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ,~ Plugging .:, Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska: Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 537' FSL, 53' FEL, Sec. 14, T11N, R8E, UN At top of productive interval 1282' FSL, 1475' FWL, Sec. 23, T11N At effective depth 1102' FSL, 1410' FWL, Sec. 23, T11N At total depth 973' FSL, 1282' FWL, Sec. 23, T11N 11. Present well condition summary 9185 Total depth: measured 6235 true vertical , R8E, UM , R8E, UM , R8E, UM I , feet Plugs (measured) feet 5. Datum elevation (DF or KB) RKB 130' 6. Unit or Property name Kuparuk River Unit 7. Well number 2A-05 feet 8. Permit number 84-67 9. APl number 50-- 103-20030 10. Pool Kuparuk River Oil Pool Effective depth: measured 8979' feet true vertical 6096' feet Junk (measured) Casing Length Structural Conductor 104' Surface 3209' Intermediate Production 9060' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Packers and SSSV (type and measured depth) Measured depth 16" 175 Sx Cold Set II True Vertical depth 9-5/8" 1000 Sx Permafrost E 250 Sx Class G 7" 350 Sx Class "G" 250 Sx PFC 8692' -8730', 8762' -8784' 5908'-5930' 5950'-5965' 104' 104' 3209' 2619 9060' 6152' , 8796' -8855' MD RECEIVED 3-1/2" J-55 at 8791' Baker FHL Packer @ 8530', Baker FB-1 Packer @ 8743', Baker FVL SSSV ~ 1893', 12.Attachments Description summary of proposal ,t~ Detailed operations program [] BOP sketch L---] 13. Estimated date for commencing operation November 25, 1987 14. If proposal was verbally approved Name of approver )~, ~jc,~,~Lg~ Date approved 15. I hereby certify that the foregoing is tCJe and correct to the best of my knowledge Signed /"~ ~'" 7 r~ ' ~t'~ ~'~'c~'¢-'~/~? Title Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness I Approval No.¢ [] Plug integrity [] BOP Test [] Location clearanceI ---~'/' ~3' M¢c~",.~n~,.':~i ,,,. ..... ~.,,' '~; ..... ~ Approved Copy ,~ -. , .... ~ Returned ORIGINAL SIGNED BY _,//-~,~':l-~, by order of LONNIE C. SMFI'ti Commissioner the commission Date Form 10-403 Rev 12-1-85 -, · .,:'Ii i Submit in triplicate(~ Kuparuk Well 2A-5 Well 2A-5 is a selective single completion currently utilized as an A Sand producer. Surface modifications will be performed to convert the well from A Sand production to A Sand, and/or C Sand injection. ARR-tc'O016 ARCO Alaska, Ir' ~-~ Post Office. m 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 20, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are on Kuparuk wells. The wells are Well Action 1G-5 Convers i on 2A-4 Conversion 2A-5 Conversion Commission multiple Applications for Sundry conversions as listed below. Anticipated Start Date November 30, 1987 November 25, 1987 November 25, 1987 Approvals If you have Sincerely, any questions, please call me at G. B. Smallwood Senior Operations Engineer GBS:pg:0129 Attachments cc: File KOE1.4-9 265-6840. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany --'" STATE OF ALASKA -' ALASK,-, OIL AND GAS CONSERVATION COMN. .,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Othe~ [] 2. Name of Operator Stimulate [] Plugging [] Perforate [] Pull tubing [] 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 537' FSL, 53' FNL, Sec. 14, T11N, R8E, UH At top of productive interval 1282' FSL, 1475' FNL, Sec. 23, T11N, R8E, UH At effective depth 1102' FSL, 1410' FWL, Sec. 23, T11N, R8E, UM At total depth 973' FSL, 1822' FWL, Sec. 23, T11N, R8E, UM 11. Present well condition summary RKB - 130' 6. Unit or Property name Kuparuk River Unit Total depth: measured 9185' feet true vertical 6235' feet Effective depth: measured feet true vertical 8979' feet 6096' Casing Length Size Structural Conductor 104' 16" Surface 3209' 9-5/8" Intermediate Production 9060 7" Liner Perforation depth: measured true vertical Plugs (measured) Junk (measured) 7. Well number 2A-5 8. Approval number 84-67 9. APl n~,~er 50-- - 20030 10. Pool Kuparuk River 0il Pool Cemented Measured depth True Vertical depth 8692' 8796' 8796' 104' 104' 3209' 2619' 175 Sx Cold Set II 1000 Sx Permafrost E + 250 Sx Class G 350 Sx Class G 250 Sx PF "C" 8730' MD 5908' - 8784' MD 5950' - 8855' MD 5973' - ,o o, R EC 5930' TVD 5965' TVD AUG 1:3 1987 6103' TVDAlaska 0il & Gas Cons. Commis,, Anchorage Baker FVL SSSV @ 1893' Tubing (size, grade and measured depth) 3-1/2" J-55 @ 8791' Packers and SSSV (type and measured depth) Baker FHL Packer @ 8530' Baker FB-1 Packer @ 8743' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (Injection) 15450 2000 3218 Subsequent to operation (Producer) 31 3 227 0 1600 175 14. Attachments Daily Report of Well Operations~] Copies of Logs and Surve. x~s Ru._~n [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1¢i~ Title 4/16/87 Date/~., / 7, Submit in I~'uplicate [on r2 ~b-ji-b?'"%:56 T-G99 KUPOPN PROD??3? , ARCO Alaska, Inc. DRILLSITE STATUS REPORT DATE: 5"'3C)~87TIME: S I:~! .,, FBEAN PSJ, ESI TEMP MCF TOTAL SI/HR REMARK /.fA/m~,~s~ ¥~ ,, lo /?~ ~3 ~ ~ t~ ,, /~.,, ~0 ~ !~ ~'~ ~o /o] ~~' ~ . . i i .. .-- i ,, . J .. I i I, I I , 5 MAXIMUM INJECTION WE STATUS CHART TOTAL TOTAL METER CALC INJ INJ TOTAL MM$CF BBLS MMSCF GAS CORR FACTOR :~'"/"'~ HEADER PRESS ~RILL'$1TE I 'PROD I TEST J PR6D J TEST J HEATER I TEMP ! TEMP COMMENTS: TOTAL FOR D.S. I I OPE BAfH I BLANKET TEMP~ GASPSI ,, RATORS SIGNATURE: CHEMICALS TYPE GAL/DAY RUN TIME 9 '19~7 _~BSJfB 0J[ & gas CONS. Commission .., Anchorage ARCO Alas: Inc. 7-_;~7 ,. , . "MAxi'MUM I INJECTION WEIrL STATUS WELL I Z ALLOWABLEI ..... NO. N o pi..... J NE {NJpsl/,.._~WH T , . CHART TOTAL TOTAL ~ PSI EFM CBHE~O~iE 7" CSG 10" C, SG METER CALC INJ INJ WELL PSi PS,[, TOTAL MMSCF BBLS MMSC, F SI/HR ':z' ~--z c ~ /N ~ I/~5' ~' ~,~ lq, i,~ (.J l. ~ ~,~~ _~-~oo ~cb ~,w,~a /a~ /~.~ _ '' ~ -- L ," ..... ~ J TOTAL FOR D.$.I le,~ ) ~--~, ,,. HEADER, , PRE~ = i -. - ~ ~_ ~ / ._ //G ~ 1375" "DRJ'LL SITE PROD TE~T' PROb TEST BATH BI_~'NkET ROll"TIME HEATER TEMP T_EMP PSI PSI TEMP GAS PSI ,. .5"~. .5')-, ,I'TO ict~ .... ~ COMMENTS: CHEMICALS TYPE 'GAL/DAY ,, , RECEIVED AUG 1 9 ifi87 Alaska 0il & (]as gons. Commission Anchorage Alas: Inc. DRILL~ITE STATUS RI~PORT DATE: ~..- ~,,~-'8 ,'~, TIME: ,~. ~ (~ DRILL$1TE ~ A L f ~ P~.O. DU.CT~O,_W.SU. ST*TUS · ~ ~ ~P TEMP CHOKE~ 7" CSG 10" CSG INJ. S ~1 F BEAN PSi PSI T~ ~ WELL . SI/HR REMARK , . . MCF ,,, /..... PA /~ ~ ~ O ~ ~ . _ _ ~ _ ~ ,= , ..... _ .. . ~ , ,, _ . ..... , , ~' frO0 TOT*L >W 2.. 37~- , L ,- " 'I 'MAxiMuM INJECTION WELL STATUS ~K~LL iN ~ !ALLOWABLE ........ - 'I'~TAL ' TOTAL · · J ;,. ir', ' ~ CHART ~ P$~ TEMP CHOKE 7" CSG 10" CSG METER CALC INJ INJ WELL ~ _ _ ./-' _~.. F B~N ~1_ . p~l TOTAL MMSCF BBLS MMSCF SI/HR ...... ~ ~ H .... 3. q~ ' ~ , ~ -q,~ ' ~.~l C--~ H~ADERP"ESS r~ TOTAL FOR D.S. CPI DRiLL SITE --PRO~ TEST ' PROD ' TE~T. BATH BLANKET RUN TIME HEATER ,I'EMP TEM,P , PSi PS!, TEMP ,GAS PSI ~o IN ..... /<~o. ::z~_ p..,-/ orrI &O/~q . 1(,5' /9.Z . , , GOMMENTS: CHEMICALS TYPE GAL/DAY , , J.'..~O .. Alaska Oil & Gas Cons. Cornmissio~ Arid~i( ARCO Alaska, Inc. ~ Post Office by^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 8, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate is an intent notice on Kuparuk Well listed below: Well Action Anticipated Start Date 2A-5 Conversion May 25, 1987 2A-5 as If you have any questions, please call me at 265-6840. Sincerely, G. B. ~mallwood Senior Operations Engineer GBS'pg-O089 Attachments cc: File KOE1.4-9 ARCO Alaska, Inc. Js a Subsidiary of AtlanticRichfieldCompany ~'" " STATE OF ALASKA ' ALAS. , OIL AND GAS CONSERVATION COM,...~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program I]XPlugging [] stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska. Inc, 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 537' FSL, 53' FEL, Sec. 14, T11N, R8E, UM At top of productive interval 1282' FSL, 1475' FWL, Sec. 23, T11N, R8E, UM At effective depth 1102' FSL, 1410' FWL, Sec. 23, T11N, R8E, UM A~'~sti~l ~l§~_t,h 1282' FWL, Sec. 23, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB - !30' feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2A-5 8. Permit number 84-67 9. 5o-- 20030 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 9185' feet 6235' feet Plugs (measured) Effective depth: measured true vertical 8979' feet 6096' feet Junk (measured) Casing Length Structural Conductor 104' Surface 3209' Intermediate Production 9060 Liner Perforation depth: measured true vertical Size 16" 9-5/8" 7" 8692'- 8730' MD 8762'- 8784' MD 8796'- 8855' MD Tubing (size, grade and measured depth) 3-1/2" J-55 @ 8791' Packers and SSSV (type and measured depth) Cemented Measured depth True Vertical depth 175 Sx Cold Set II 1000 Sx Permafrost E 250 Sx Class G 104' 104' 3209' 2619' 350 Sx Class G 9060' 250 Sx PF "C" 5908' - 5930' TVD 5950' - 5965' TVD 5973' - 6103' TVD 6152' Baker FHL Packer @ 8530', Baker FB-1 Packer @ 8743', Baker FVL SSSV @ 1893' 12.Attachments Description summary of proposal [DX Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation May 25~ 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the .~est of my knowledge Signed ~/~ A J.,~"~-.¢~-~"L~,-i~-¢';~ Title .x~l- ~/)/'~.,~%,..~..~--'c~,-vt.~ ~'~.b~/ ' ' Commission Use O-Ylyn U Date Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ~ek.,mod ~" :-- ~ ~ Commissioner Approval No. 7 _ 3,,,Ch by order of the commission Date 7 Form 10-403 Rev 12-1-85 Submit in triplicate ATTACHMENT Kuparuk Well 2A-5 Well 2A-5 is a selective single completion currently on gas injection service. Manifolding will be set up to put the well on production service and downhole well work will be performed to shut in the C Sand and open up the A Sand. JBS'tc'O067 ARCO Alaska, Ir'-'"' Post Offic~ 8ox 100380 Anchorage,~ Alaska 99510-0363 Telephone 907 276 1215 DATE: 08-16-85 TRANSHITTAL NO: 5254 ARCO ALASKA, INC. KUPARUK -OPERA%'IONS ENGINEERING ., RECORDS CLERK ATO-1115B P.O. BOX 1U0360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE RECEIPT AND RETU~ PRESSURE FINALS CAHCO lB-3 1D-8 1E-5 1H-6 iL- 2 1L-5 lQ-6 lQ-9 2A-5 2A-5 2C-4 2F-7 2F-8 2F-9 2G-1 2G-1 2U-5 2U-6 2U-7 2U-8 2X-'l 0 OTIS 2A-2 .!. 2u-i4 '~ 2V-'2 ~ 2V-5 2V-!3 2V-14 .~ 2W-7 > 3B-3 ~ 3B-8 _ FOLLOWING ITEHS. PLEASE ACKNOWLEDGE ONE SIGNED COPY OF THIS TRANSMITTAL. PBU 04-21/22-85 STATIC 04-29-85 PBU 04-26-28-85 STATIC 04-29-85 PBU 04-24/25-85 PBU 04-28/29/85 'PRESSURE FALL OFF 05-07-85 PBU 05-12/13-85 PRESSURE FALL OFF 04-21/22-85 .' STATIC 05-05-85 PBU 04-24/25-85 PBU 04-14-85 PBU 04-19/20-85 PBU 04-13/14-85 STATIC 04-17-85 PBU 04-29-85 STATIC 05-02-85 STATIC '-05-03-85 STATIC 05-04-85 STATIC 05-04-85 PBU 04-25/26-85 STATIC 07-04-85 'PBU 06-30-85 PBU 07-27-85 PBU 06-25-85 STATIC 06-22-85 STATIC 06-22-85 PBU 07-26-85 STATIC. 06-28-85 STATIC 06-28-85 -RECEIPT ACKNOWLEDGED: DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON 'HOBI L* PHILLIPS OIL* NSK CLERK J. RATHMELL* BPAE*' -B. CURRIER CtiEVRON* D & M* : Anch0ra.a6 . STATE OF A~ASKA'~ SOHIO* UNION* K. TULIN/VAULT RETURN. TO: ARCO Alaska, Inc. ~ . Post Office B~..~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-19-85 TRANSMITTAL NO: 5230 PAGE 1 OF 2 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. :BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERE%~ITH -ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE, FLUID,. AND ACID DATA ~%~ SBHP 05-3 0-8 lB-2 lB-4 lB-4 ID-8 1E-iA 1E-5 1E-11 1E-23 !E-23 !E-27 1E-27 1G-6 1H-6' 1L-5 1L-5 - lQ-1 ~ ~!Q-! lQ-3 lQ-4 iQ-4 lQ-4 iQ-5 iQ-7 !Q-9 lQ-9 1Y-12 2A-2 2A-4 2A-4 2A-4 SBHP- SBHP- PRE-WORKOVER SBHP TUBI~]G LEAK COMP PBU ETC. LEUTERT BI{ SMPL SBHP SBHP TEMP/SPIN-LEAK TUBING LEAK PRESSURE FALL- OFF SBHP' PBU W/E-LINE PBU ISIP SBHP 'A'SDS TAG FILL BHP SBHP 'C' SD ETC SBHP ETC ACID JOB':' ISIP TEST ACID JOB 'C ' SD PBU PBU 'C'SD ETC FALL-OFF TEST BHP 'A 'SD BHP 'A 'SD BHP 'A 'SD BHP (ONE COPY OF EACH) 5 CAMCO 05-30-85 CAMCO 05-16-85 CAMCO 05-24-85 CAMCO 04-2 9-85 CAMCO 05-03-85 CAMCO 04-2 8-8 5 CAMCO 06-02-85 OTIS 05-22-85 CAMCO 05-23-85 CAMCO 05-0 3-85 CAMCO 05-04-85 CAMCO - 05-0 7-85 CAMCO 04-29-85 04-27-85 04-29-85 05-30-85 05-26-85 05-18-85 05-10-85 05-14 -85 05-17-85 04 -29-85 05-26-85 05-12-85 05-13-85 05-05 -85 05-27-85 05-10-85 05-09-85 05-11-85 CAMCO CAMCO. CAMCO B. J. HUGHES CAMCO CAMCO CAMCO CAMCO NOWSCO/B . J. HUGHES B . J . HU GItE S . NOWSCO/DOWELL CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO -~-~ SBHP 05-0 5-8 5 CAMCO ***CONTINUED ON THE 'FOLLOWING PAGE*** RECEIPT ACKNOWLEDGED: 3P~E*~ DRILLING W. PASHER ~. CURRIE-R L. JOHNSTON EXXON ~_H'EV~oN* MOBIL* '~PHILLIPS OIL* ~ & M-F NS K CLERK J. p~ATHMELLj~ Commission DATE: [[.~. ,, S TAT E '"'0F,'~:' ALA'~'~A .~,_ ~'-'~': ¢'OHIO* : · UNION* K. TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCornpany RETURN TO: ARCO Alaska, Inc. ')st Office Box 100360 ,.mchorage, Alaska 99510-0360 Telephone 907 276 1215 TRANSMITTED RECEIPT AND RETURN SEQUENCE OF EVENTS PRESSURE lB-1 lB-2 lB-4 lB-4 ID-8 1E-lA 1E-5 'iE-ll 1E-23 1E-23 1E-2 7 1E-27 1G-6 33/-6 1L-5 1L-5 lQ-1 .!Q-1 lQ-3 lQ-4 iQ-4 iQ-4 lQ-5 lQ-7 lQ-9 lQ-9 1Y-1 2A-2 2A-4 2A-4 2A-4 DATE: 06-19-85 TRANSMITTAL NO:5230 PAGE 1 OF 2 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO- 1115B P.O. 'BOX 100360 ANCHORAGE, AK 99510 · HERE%.qITH .ARE THE FOLLOWING ITF~S. PLEASE ACKNOWLEDGE ONE SIGNED COPY OF THIS TRANSMITTAL. FROM WELL SERVICE REPORTS (ONE COPY OF CAMCO 05-30-85 CAMCO 05-16-8 5 CAMCO 05-24-85 CAMCO 04-2 9-85 CAMCO 05-03 -85 CAMCO 04-28-85 CAMCO 06-02-85 OTIS 05-22-85 CAMCO 05-23-85 CAMCO 05-0 3-85 CAMCO 05-04-85 CAMCO 05-0 7-8 5 CAMCO EACH 04-2 9-85 CAMCO 04-27-85 CAMCO 04-2 9-85 CAMCO 05-30-85 B.J. HUGHES 05-2 6-85 CAMCO 05-18-85 CAMCO 05-10-8 5 CAMCO 05-14-85 CAMCO 05-17-85 NOWSCO/B . J. HUGHES 04-29-85 B.J. HUGHES 05-2 6-85 NOWSCO/DOWELL 05-12-85 CAMCO 05-13-8 5 CAMCO 05-05 -85 CAMCO 05-27-85 OTIS 05-!0-85 CAMCO 05-0 9-8 5 CAMCO 05-11-85 CAMCO 05-0 5-8 5 CAMCO , FLUID,. AND ACID DATA SBHP 05-30-85 SBHP' SBHP PRE-WORKOVER SBHP TUBI~;G LEAK COMP PBU ETC. LEUTERT Bt{ SMPL SBHP SBHP TEMP/SPIN-LEAK TUBING LEAK PRESSURE FALL- OFF SBHP PBU W/E-LINE PBU ISIP ~ SBHP 'A'SDS TAG FILL BHP SBHP 'C' SD ETC SBHP ETC ACID JOB"' ISIP TEST ACID JOB 'C ' SD PBU PBU 'C'SD ETC FALL-OFF TEST BHP 'A 'SD BHP 'A '-SD BHP 'A 'SD BHP PA GE * * * DiS'£R-rB U TION: %.~. PASHER EXXON PHILLIPS OIL* J. P~ATHMELL J' ~C~0NTINUED 'ON THE'FOLLOWING RECEIPT ACKNOWLEDGED: BPAE* DRILLINC B. CURRIER L. JOHNSTON CHEVRON* .HOB IL * D & M.~' NS K CLERK DATE: SOHIO* . U~'~ION* K. TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary ol AtlanticRichfieldCompan)' ARCO Alaska, lnc Post Office [5ox 100360 Anchorage, Alaska 99510-0360 Te!ephone 907 276 1215 DATE' 05-2 9-8 5 T1ZANSMImm''~.~n~ NO:5°03_ RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK , ATO-11!SB P.O. BOX 100360 ANCHORAGE, AK 99510 TIQ%NSMITTED HEREWIT)f ARE TIIE b'OLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THiS ,. S,'.QU~NCE OF EVENTS .RE~URE DATA '2A-3 PBU- '~' SAND 2A-5 SBHP -2B-1 PBU 2B'2 PBU 2B-15 PBU- POST FRAC ~2B-16 PBU 2F-7 PBU- STATE [['~]~ ~[3~ PB U- ' A' $ AND 2 E~.~/PB U- STATE f2-G-2~.~' PBU 2G-!2 PBU- 'A' SAND POST FRAC 2H-15 ISBHP 2W-13 PBU- 'C' SAND 2X-13 PBU 03-16-85 11-21-84 04-01-85 04-02-85 04-09-85 04-10-85 04-14-85 04-20-85 ....... 04-13-85 04-11-85 03-23-85 04-10-85 04-21-85 03-30-85 PLEASE ACKNOWLEDGE TFJ~NSMI TTAL. BAKER/ LYNES PRESSURE (ONE COPY OF EACH) L"D ,pc' R,~,. OR~ SET DEPTH lA-1 PDU 04-23-85 7187 ' !A-2 PBU 04-23-85 7476 ' lA-2 PBU 04-23-85 7476 ' lA-5 BUILD-UP 04-23-85 6957'' lA-6 PBU 04-23-85 8300 ' lA-6 BUiLD-UP 04-23-85 8300 ' iA-10 BUILD-UP 04-23-85 8415 ' lA-10 BUILD-UP 04-23-85 8415 ' TOOL NO. 1722 1302 1512 1734 1719 2062 1508 1299 RECEIPT ACKNOWLEDGED: 3 PAE * '.3. CURRIER* £ lI,E VROi-] * 3 & M* DRILLING L. JOHNSTON MOBIL* N~:~ CLERK DISTRIBUTION: W. PASIIER ~-, -. X XO N PHILLIPS OIL* J. RATIiMELL* DA~a o, & b,~ Cot,s, Commissiorl Anchorage STATE OF ALAS SOHIO* UNION* K.~u~"N/VAULT ARCO Alaska, Inc."'"' Post Office r.,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 D A 'I,' E ' 05 .... i 5 ...,.,° _% 'F R A i'li I'i I ]" 'T ,-.~ L. N 0-~':' ARCO AI..A,'?I".A, :liNC. A T T N: h' El C 0 R I) 5; C L.. I-Z R A]"O--lt iSB I::'.[1. BOX i00369 ANCHOF;:,-?~(.;li'Z', Al( 995i !' t';: A N,':7 H I l' T E: D I--I I:!: I:;: [_.- H ]: T ',:ECEIF'I' AND F;:I-'""I'URN, H A i:;1 E: 'l'li Iii: I'* 0 I_. L. 0 W ]: iW [, (:) N E" 5' :[ (]-N I:[ D I T Iii: H ;.'.,', F:' I... I-'ii A 5,' IE A C, I( i'~. ii ;J L. r." 1) 6 I.'!: C 0 F:' Y 0 F.' 'i' 1..11 $ 'f' R A N 5' M T T T A L, t" ", ' t', ..... x d., I-,,/.~[:.(~lJEl',~(.,f.'E. OF:' I:_':VEN'¥S' :?.C-4 ".'-.' C-4 '?.C-5 ~.:.'C-5 2 C- t 4 .?. C-- t 4 .:.:'. I) -" t G 2. I)- f 0 '2 I.---- 6 :Ct F - 8 2F--8 2F'--t '?.F'- I t 2[4- t 2 (.; -. t 7.-.' [,; --' 8 2G--8 :':: E: C Ii:' l F' T ::-:. C [.J R R 7 I--1 lie V ) ,.t, M, R U N L_ Y N ["' S R E C (:)R 1.." [ii R,!.;' R I."] l' R I l'l V E L_ Y i",! IiE )_; R Ii'- C. 0 R D E F;: S' · ~ I'"' ~''' L '~ N,:'-.~ F:;R E.~ 5' U I:;: E Ii; D M D 5'-" P BtJ SDHF' 'C' S'AND 'C' 5'AND3 ONLY I::'BLI 'C' :.~AND F'BU TAG F'-ILL/SBHP TA(; F'[I...L./5'BHF' ' A' $'AN.D.? $ ii',' I-'1P 5'BHF' F"ALL OI'-'F TEST F:AI..L.OF'-F TE:';'T ,.~ Ii',' I"1F' I"-/I._INE ,S'I::'IN/T[.:L ,:?UI:;:VEY LEAK DETECTION 'C'SAND F'BU F'BU RUN TORQUE TL!RN/AHEi:;,'ADAS PBU--I::'ULL TORQUE TUF;:N/ A Hr-i:RAI)A BOHBS R. tJN TORQUE TL~F;:N/'AkiEF:;ADA~'7 F:'I!-,'IJ-F:'UI..1.. TOI:;~DUI-" ]'URN/ AHERADA BI]NBS RUN 'FOF;:qL!E TUF;:N/AHI-'-':I:;:AI)A,? RUN TORQUE ]"LIF;:N/AMI:"'F;:ADA$ I'--'I-.';LI--I:'LII_.L TORC',~UE 'FUI"(N/ A- MEI-',tA D A BOHBS F'BIJ F:' Ii: II I"" B U F'BU F'BU PBU F:' I) U i"" I-) U F:'BU ACKNOWLI:i:I)GEI): D i:~.'. I L L I N !] I!!: R * .I ..... J(.i H H S ]" 0 hi N,'.it K C LIE F:: K 0'! '"'2 t .... 85 01' I S' 04--.'~''~--'° <,,:.,-_ ,.,., O'FIS 04 -' 2 t - 8'5 [) l'I S' 04-26-'85 CAMCO 0 ,I -, 2 i -' 85 C A M C (:) ~4-25-85 CAMCO 04-2~-85 CAMCO 04-1 6-85 CAMCO 04-22-85 CAHCO 04- '') '~ o,.- 0,1 -2 t - o 5 C A H C [) - d .> C A H C 0 ~ 4 .-.'~ "~,:.,. ,' ,~ O4-?3-85 OTIS O4-"i 6-85 OTIS 04-24-85 CAMCO 04 - 25 _...... o ~' .~ C A M C [) 6'4-2t -8.5 I"~AI( E I:;1 O. :~ -' ,,-. 3 _,-,° 04-2t -85 04 -2 t -.li)':'..~ 04-21 -85 04-20-"8~ 04- i 8-85 04-i '" '"~ 7 --' (.') ..1' 04- i 7.--85 (-) 4 .- t 8 --85 03--2t -85 '7 --. "') "'") ~ 0 I.~ BAI< ER/T[)I';:QUF ]'URN OT1 $ BAI< ER/I'OF(QLJE I'URN 0 T I S B A I< E R BAI<ER/I'ORQUE I'URN O'F I S CAMCO . .-. r \/rD C A H C 0 CAMCO l~('~ ~ t, ,, .~ ,-, A/as~e Oii& G~s r,,, 6) T ]; ,~ ~'~,]S. O0;~hTl/SSlOh - O'l' I S ~achora0e D A T E · . ...... ¢ · STATE OF ALAYI(A · S 0 I-.I I 0 · U N I 0 N K, TU[.I?~/VAULT ARCO Alaska, Inc. ~--'-- Post Office Bc .00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton: Enclosed are revised Well Completion Reports for the following wells: 2A-2 2D-5 2E-14 2A-3 2D-14 2E-]6 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the cement quantity used when each well was Arctic Packed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures RECEIVED APR 2 2198§ Alaska Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany "--" STATE OF ALASKA -~- ALASKA:. ~-AND GAS CONSERVATION CL ~,VIISSION ' _W_EL__L COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISION ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE of Operator ARCO Alaska, Inc. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of well at surface 537' FSL, 53' FEL, Sec. 1/+, TllN, RSE, UN At Top Producing Interval 1282' F,SL, 1/+75' FWL, Sec.23, TllN~ RSE~ UN At Total Depth umber ~,;,t o~ Lease Name i ver Unft We/_/Number 973' FSL, 1282' FWL, Sec.23, TllN, ESE, UM 11. FieJd and Pool 5. Elevation in feet (indicate KB, DF etc 130' RKB ' ') ~esignation and Serial N~ Kuparuk Rfver Field -- I ADL 25570 A" paruk R~ver 12, Date Spudded ....... ~u~ Z~bTO ALK 2668 0~] Pool o~/o~/8~ I'~~~~~ b~~~= - ~ · , ~. ~oana 15 1~ 06/28/8~ · · Water Depth, if offshore . zu. uepth h ~~~ y w ereSSSV set TyPe Electr,c or Other L .~.,,. ES~X NO~ I ~'1~ . _ o ....... [ 193. feet MD I l~nn~ z DIL/SFL/GR/SP/FDC/CNL/Ca]~ CBL/VDL/GR/CCL~ GSro Z ,~uu- ~approx) 23. ' ~ ~ CASING, LINER AND CEMENTIN( RECORD CAS?_G SIZ.___~E WT. PER FT. GRADE -~,,~ SETTIN? DEPTH MD ,x PF "C" :24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number} 8816' - 8836' w//+ spf~ 90° phasin 8762' ' 878/+' RIAL USED GAS-OIL RATIO ~PS and presence of oil gas or water. Submit core chips, Form 10-407 Rev. 7-1-80 JMN2/WCO/+ RECEIVED APR ~ 21985 Alaska Oil & Gas Cons. Commiss[o~ Anchorage CONTINUED ON REVERSE SIDE Submit in duplicate d~''-'~ . , ¢ · .. ~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and_time of.each phase. . . Top Upper Sand 8692' 5903' N/A ' ' Base Upper San~J' 8728~ 5927~ Top Lower Sand ;~: - 8738' 593zi' Base Lower Sand 8965' . 6087~ .... ;.~,~.. , :. ~ .. . ! ,'.. : ~ :. ,~ ., · : . . . · . t -- , , ,· ~ , -. ~ ..~ r: -.. . · , . '" ~ .'i" ' . : · . .[ .- .. . .. . . . . , , · __ 31. LIST OF ATTACHMENTS ' . Nt~Fle · , · - .' , - t " ...... 32. I hereby.certi:fy that the foregoing is true and correct to the best of my knowledge -. ~ - INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on- all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, ~ir. injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state, in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23. Attached suppleme.n, tal records4or this well should show the details of any multiple stage cement- ing and the location of the cementing tool Item 27: Method of Operation' Flowin~g, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 UNIT 4. Location of Well SURFACE LOCATION- 537'FSL, 53'FWL, Sec, 14, T11N, R8E, UM BOTTOM HOLE LOCATION' 1128' FSL, 1147'FWL, Sec. 23, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. RKB 130' PAD 9'4'I ADL 25570 ALK 12. 7. Permit No. 84-67 8. APl Number 50- 103-20030 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 2A-5 11. Field and Pool KUPARUK RIVER KUPARUK RIVER 2668 P00t Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data FIELD OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On March 12, 1985, Kuparuk well 2A-5 was converted from a producer to an injector. Injection will be in the "C" sand only. RECE!VED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK The space below for Commission use COORDINATOR 3/28/85 Date~_~ .. Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: on We l ! Action Date Pe, rformed 1E-6 Fracture 1/26/85 1E-7 Reperf 1E-7 Fracture 3/1/85 1E-8 Reperf 1/28/85 1E-11 Reperf 2/1/85 1E-11 Fracture 2/7/85 1E-18 Fracture 3 / 13 / 85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3 / 23 ! 85 1E-22 Fracture 3/22/85 1E-24 Fracture 3/22/85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3/18/85 1Q-10 Fracture 3/5/85 1Q-12 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Conversion 3/12/85 2A-6 Conversion 3/12/85 2A-7 Conversion 3/12/85 2C-4 Reperf 2/23/85 2D-4 Reperf 2/2/85 2V-8A Conversion 2X-8 Perforation 1/27/85 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) the ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, ~ Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to stimulate Kuparuk Field well 1F-6 and to convert the following wells: 1Y-2, 1Y-8, 1Y-12, 1Y-15 2A-l, 2A-2, 2A-3, 2A-4, 2A-5, 2A-6, 2A-7 2V-l, 2V-2, 2V-3, 2V-4 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED J^N 0 4 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA ~31L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-67 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 103-20030 OTHER [] 4. Location of Well SURFACE LOCATION: TllN, R8E, UM 537'FSL, 53'FWL, Sec. 14, BOTTOM HOLE LOCATION: 1128' FSL, l147'FWL, Sec. 23, TllN, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. I 9. Unit or Lease Name KUPARUK RIVER UNIT 12. 10. Well Number 2A-5 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL RKB 130' PAD 94' ADL 25570 ALK 2668 POOL CheckAppropriateBoxTolndicateNatureofNotice, Report, orOtherData NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other ~--, Pull Tubing [] Other {~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 2A-5 be converted from a producer to a gas injection well. The well has produced from both the "A" and "C" sands. For injection, however, the "A" sand will be blanked off and injection will be in the "C" sand only. ANTICIPATED START DATE: January 25, 1985. RECEIVED 0 1985 ,-11aska 0ii & Gas Cons. C0rnmissi0n Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed k,~(~ j _ Ti~,e OPERATIONS COORDINATOR The space below for Commission use Date 1/3/85 Conditions of Approval, if any: Approved by 6RII~IliAL S!GIIEB · B! LOflHIE C. SMITH Return~.~ By Order of COMMISSION[R the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.~, . u,, ~.':.¢ 35C~ ,- '. i =O:~O-..'. 5ka °crlO 9 ~:e~hone 907 277 5637 Date: Transmi~al No 4740 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 :h. :' -c ~ c.5- Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. S CHLb~ERGER FINALS/PRODUCTION ~? 2G-7 CBL "Variable Density" "GCT/4" HJ" 2G-7 Completion Record "CBL/VDL/GCT" 7/13/84 Run 5 7/14/84 " 6000 - 6459 6000 - 6423 2B-9 CCL & Perf. Record 7/18/84 Run 1 2B-8 CCL & Perf. Record 7/13/84 " .2B-7 . CCL & Perf. Record 7/lO/84 " 2A-5 Completion Record "PPS/JB" 6/26/84 " 8.600 - 8920 1F-2 Completion Record "Sq. 4" Retain" 8/02/84 1F-2 .Completion Record "Set Plug & Retain 8/03/84 " 7400 - 7750 Run 2 7450 - 7690 1F-2 CCL '& Perf. "Perf & Packer Set" "CBL/Plug Retain/JB" ~;:~ 1F-2 CBL -"var iable Density" "Packer Retain/Perf/JB" 8/06184 8/05/84 6950 - 7935 'lG-4 CBL "Variable Density" 1G-4 Depth Determination Log "CBL" 1G-13 EPL "Tracer" Receipt Acknowledged: 8/1'!/84 8/11/84 7103184 Run 3 5964 - 6903 Run 1 5934 - 6548 " 7400 - 7941 Date: /cat DISTRIBUTION B. Adams D & M W.V. Pasher ~ ' ~ '-'- ~ ' G. Phillips P. Baxter :''~ ~':'::' .'~,~/:~C~~;y ~'-'-' ) Phillips Oil BP/~E "~-~ '''~~,..,:..,-,, Mobil- ~ J' J' Rathmell R&D Chevron KSK Operations C. R. Smith ~State of Alaska Sohio Union Well Files ARCO Alaska, Cc.~.: ©~ .~c::,' 365 Anchorage. Alaska 99510 Telephone 907 277 ..5637 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 8/17/84 Transmittal No: 4691 Transmitted herewith are the following items. Please acknowledge receipt and return-one signed copy of this transmittal. CH FINALS/Schlumberger 1G-16~ CBL Variable Density 5/29/84 8800 - 9050 Run 1 2A-lA CBL " " GCT 6/02/84 5895 - 7502 " 2A-2~'" CBL " . " GCT 6/02/84 5291 - 6544 " 2A-3'f~' CBL " " CIS 6/01/84 4948 - 7092 " 2A-4~ CBL " " 6/01/84 6750 - 8018 " 2A-3j CBL " " CRS/RTS/DDL 6/15/84 6583 - 7081 Run 2 & 3 2A-5 .r CBL " " 6/03/84 7695 - 8938 Run 1 2A-6. CBL " " 6/03/84 6995 - 8078 " 2A-7 ~ CBL " " GCT 6/03/84 6895 - 7823 " 2A-lA ~ Gyro Cont. Tool "CBL/VDL" 6/02/84 60 - 7454 " 2A-2 -'~ " " " " " 6/04/84 60 - 8060 " 2A-3/ " " " " " 6/02/84 60.5 - 7050 " 2A-4~ " '" " " " 6/02/84 60.5 - 8003 " 2A-6 ~ " " " " " 6/04/84 60 - 8060 " 2A-7~- " " " " " 6/04/84 Surf - 7805 " /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron DISTRIBUTION Drilling W.¥. Pasher G. Phillips Geology ~--~ Phillips Oil ~ Mobil J' J' Rathmell NSK Operations R&D C. R. Smith Sohio Union Well Files ARCO Alaska, Inc. Post Office b...^ 100360 Anchorage, Alaska 99510 ~ Telephone 907 276 1215 August 8, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2A-5 Dear Mr. Chatterton: Enclosed are the Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU8/L91 Enclosure RECE)V£D Naska 0it & Gas Cons. commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany --- STATE OF ALASKA --~ ~_-~./ ALASKa' ~ AND GAS CONSERVATION C~_ ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1, Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-67 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20030 4. Location of well at surface~LOC ~S~ .'r'~_/~5~ 9. Unit or Lease Name 537' FSL, 53' FEL, Sec.14, T11N, R8E, UN Kuparuk River Unit VERIFIED At Top Producing Interval I ~ 10. Well Number 1282' FSL, 1475' FWL, Sec.23, T11N, RSE, UM /Surf' ~---~---~ 2A-5 At Total Depth I ~' id' ~-~---~ 11. Field and Pool 973' FSL, 1282' FWL, Sec.23, T11N, R8E, UN~ Kuparuk River Field §. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKBI ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/06/84 05/13/84 06/28/84I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9185'ND, 6235'TVD 8979'MD,6096'TVD YES [] NO []I 1931 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, CBL/VDL/GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 104' 24" 175 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3209' 12-1/4" 1000 sx Permafrost E & !50 sx Permafrost C 7" 26.0# J-55 Surf 9060' 8-1/2" 350 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8836' - 8855' 3-1/2" 8791' 8781' & 8568' 8816' - 8836' w/4 spf, 90° phasing 8796' - 8816' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 8762' - 8784' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 8762' - 8784' 8710' - 8730' w/12 spf, 120° phasing 8692' - 8710' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ _~8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED AUG 1 4 1984 Alaska 0il & (]as Cons. Commission Anchorage Form 10-407 GRUS/WC04 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :~:: e~o~:o~C~AA~s ~--~,:~... ~. ~. ~-~ ',~ :-~ ~-~;'::.z.: ::~ .:.v .... , - , ; . .., , . NAME Include interval tested, pressure data, all fluids r~over~ and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . . Top Upper Sand 8692'.. 5903' N/A ~se Upper Sand 8728~ 5927~ lop ko,er Sand ._8738~ : 5~3~~ -- ~se Lower Sand 8965' - ' 6087' . · . . ... . -. ; . . -: . : :. . .. , - . . - . : ;- ;~ . ;-. I 31. LIST OF ATTACHMENTS _ ~,11 His~ory~ ~orkover ~ell H~s~°rv~ .GyrosCopic Survey 32. I herob~ certifg that the fore~0in~ is true and cOrreCt to the best of mg knowledge Signed Title A~¢~ Rr~l]{nn Fnnr_ Date _ . -- INSTRUCTIONS General: This form is designed for Submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion'. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Well History- Initial Report- Dally ~ ~_?4_~_.l~)~t.~ _t~B~".__l~lfl~ld_~ . .l~l~rf. ' on the .first Wedn~edly after · well Ii sl~dcled or workov~r ol~r~tlon~ ~r~ ~rt~cI. ~-- -- ~ ~ I~rmr m .;u~ng ~lo ae .umnt~lz~ mt th~ form giving InClu~ive d~tN only. Alaaka Kuparuk River Auth, or W.O. no. A~;. 901717 .-"'~'~" 'i ' I North Slope Borough Unit ADL t/25570 Drill, Complete & Perforate Alaska Vell no. 2A-5 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IDate JHour Hfs. 5/06/84 1500 iComplete record for each day reported J^Rco w.,. 56.24% Prior statu~ If a W.O. Date and depth 08 of 8:0~ a.m. 5/07/84 5/08/84 5/09/84 5/10/84 5/11/84 Tho above il correct 16" @ 104' 1400', (1296'), Navi-Drl below KOP Wt. 9.3, PV 17, YP 52, PH 8, WL 15, Sol 5 Accept rig @ 1230 hrs, 5/6/84. NU 20" riser. Spud well @ 1500 hfs, 5/6/84. Drl to 512', Navi-Drl to 1400'. 500', Assumed vertical 723', 4.5°, S42.7W, 669.83 TVD, 6.67 VS, 4.90S, 4.52W 1117', 19.0°, S44.3W, 1054.47 TVD, 86.94 VS, 63.05S, 60.06W 16" @ 104' 2288', (888'), TIH Wt. 9.5, PV 17, YP 29, PH 8.5, WL 17, Sol 5 Navi-Drl to 1567', drl to 2288', TOH f/angle bldg assy. 1561', 32.4°, S43.5W, 1453.16 TVD, 279.92 VS, 204.67S, 191.23W 1929', 43.4°, S43.SW, 1741.46 TVD, 507.49 VS, 369.39S, 348.62W 2307', 45.9°, S4t.4W, 2022.46 TVD, 783.49 VS, 572.55S, 535.01W 16" @ 104' 3229', (941'), Rn'g 9-5/8" csg Wt. 9.7, PV 20, YP 30, PH 8.0, WL 15.6, Sol 8 TIH, drl 12¼" hole to 3229', circ, TOH f/csg. 2270', 45.9°, S41.4W, 2022.46 TVD, 783.49 VS, 572.55S, 535.61W 2560', 51.6°, S41.SW, 2214.24 TVD, 1000.82 VS, 734.03S, 681.12W 3182', 51.7°, S40.gW, 2597.81TVD, 1490.40 VS, 1098.55S, 1008.03W 9-5/8" @ 3209' 3229'TD, (0'), Drl Wiper Plugs @ FC Wt. 8.5, PV 3, YP 1, PH 9, WL 19.6, Sol -2 Fin run 81 its 9-5/8" 36# J-55 BTC csg w/FS @ 3209', FC @ 3130'. Cmt w/1000 sx PF "E" cmt @ 12.3 ppg + 250 sx PF "C" cmt @ 15.6 ppg. Disp!& bump plug to 1500 psi. CIP @_1000 Hfs 5/10/84. RIH w/BHA, tst csg to 1500 psi, begin drlg plugs. 9-5/8" @ 3209' 4564', (1335'), Drlg Wt. 8.9, PV 8, YP 7, PH 9.5, WL 8.6, Sol 4+ Fin drl'g plugs, flt equip, cmt + 10' new hole. Conduct formation tst to 12.5 EMW. Drl & surv 8½" hole to 4564'. 3355', 52.9°, S40W, 2703.60 TVD, 1627.27, 1202.71S, 1096.83W 4234', 54.9°, S41W, 3214.77 TVD, 2342.23, 1737.72S, 1571.15~)~f-~1,,~, AUG 1 4 ]984 Alaska Oil & Gas Cons. Commission An~hnro,~ IDate I Title 5/23/84 Drilling Superintendent ARCO 011 and Gas ComPany Daily Well History--Interim I~clte~: Thll form il used during' drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill item teltl sequentially. Attach description of all core~. Work performed by Producing Section will be reported on "lnlerlm" sheeta until final completion. Report official or representative test on "Fhtll" form. 1} Submit "II, realm" sheets when filled out but not lese frequently Ihen every 30 days, or (2) on Wedneadey of the week In which oil string ia set. Submit ~#teldy for workovera ~d following setting of oil string until completion. Dlsfrlct Field Date and depth aa of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL #25570 Complete record for each day while drilling or workover in progress 5/12/84 thru 5/14/84 5/15/84 5/16/84 IStale Alaska Well no. 2A-5 9-5/8" @ 3209' 9185', (4621'), Prep to log Wt. 10.2+, PV i2, YP 11, PH I0, WL 5.4, Sol 12 Drl & surv 8½" hole to 9185' 4736',. 54.0°, S39.9W, 3506.64 TVD, 2750.63VS, 2048.52S, 1836.12W 5754', 49.7°, S40.1W, 4130.01TVD, 3555.04VS, 2663.93S, 2354.29W 6437', 47.8°, S40.1W, 4576.16 TVD, 4072.03VS, 3060.92S, 2685.64W 7090', 56.8°, S38.2W, 4966.62 TVD, 4594.12VS, 3466.74S, 3014.58W 7594', 56.3°, S37.8W, 5244.43 TVD, 5014.07VS, 3798.11S, 3273.47W 8452',~50.9°, S33.9W, 5749.15 TVD, 5704.36VS, 4361.69S, 3677o30W 9-5/8" @ 3209' 9185', (0'), POOH f/logs Wt. 10.2, PV 15, YP 14, PH 9.5, WL 4.4, Sol 12 RIH w/triple combo, unable to get below 7416', POOH. RIH w/BHA, stuck pipe @ 8785' Jar & wrk pipe. Mx Black Magic pill, pipe came free. Rm 8610'-9100', circ, pmp pill, POOH f/logs. 9-5/8" @ 3209' 9185', (0'), Rn'g 7" csg Wt. 10.2, PV 15, YP 11, PH 9.0, WL 5.6, Sol 13 Fin POOH. Rn triple combo f/9100'-surf csg shoe. RU to rn 7" csg. 9026', 47°, S31W, 6126.03 TVD, 6132.52 VS, 4727.14S, 3909.49W The above is correct Signature For fo'~m'-~roparetion and~lstribui'iofi see Procedures M~ual ~ction 10, DHIling, Pagea 86 ~d 87 Joale 5/23/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Fin'al Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and represerltative test data in blocks provided. The "Final Report" ~orm may be used for reporting the entire operation if space is available. District ICounty or Parish Lease or Unit Title IAccounting cost center code State Alaska Well no. 2A-5 Field Alaska North Slope Borough Kuparuk River ADL #25570 Auth. or W.O. no. AFE 901717 Drill, Complete & Perforate Operator ARCO Alaska, Inc. Spudded or W.O. begun IA.R.Co. W.k 56.24% Date 5/6/84 Spudded Date and depth as of 8:00 a.m. 5/17/84 Complete record for each day reported Iotal number of wells (active or inactive) on this i Dst center prior to plugging and I bandonment of this well I our I Prior status if a W,O, I 1500 Hrs. 7" @ 9060' 8979' PBTD, RR 10.2 NaC1/NaBr Fin rn'g 232 jts + 2 marker jts, 7", 26#, J-55 BTC csg w/FC @ 8980', FS @ 9060'. M&P 350 sx Cl "G" w/l% CFR-2, 5% KC1 & .3% Halad-24. Displ w/10.2 NaC1/NaBr, bump plug. CIP @ 1345 hrs, 5/16/84. ND BOPE, NU tree, instl pack-off & tst to 3000 psi. Inj 520 bbls excess mud, 150 bbls frsh wtr & 15 bbls diesel cap dn 7" x 9-5/8" ann. Break dn 650 psi; ISIP 420 psi. RR @ 2000 hrs, 5/16/84. RECEIVED AIJ z11984 Alaska Oil & Gas Cons. Commission Old TD New TO PB Depth 9185' 8979' Released rig Date Kind of rig 2000 Hrs. 5/16/84 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature 5/23/84 · ~J]-~ ~,~ _~-,~.~ IDate ITM Fo; f_or--"~ prepa a.t. io'n-a.~ distr;bution, Drilling Superintendent ARCO OII and Gas Compmy O Well History - Initial Report - Dally I~metie~: Prelim and eubmlt t~..-~ _'~J.J.J.J.J.J~i~ . .~. o~ the flint Wedneldly Ifter a well II IpUdded or wort<over operations are etarted. Dally werk I~le~ .t~~_ ~IT/~I~I.: bl IiImm~tzed o~ the form giving Inclualve date8 only. ;~v~..~- :. ~..~.~. District ICou.ty. p~ri~t or borough Alaska J biorth Slope Borough Field ILe~e or Unit Kuparuk River I ADL # Aura. or w.o. no. ITitle AFE 901717 I Completion IState Alaska IWell no. 2A-5 W/O Operator ARCO Alaska, Inc. Workover 6/2~/84 0600 Hrs. Date and depth as of 8:00 a.m. 6/27/84 6/28/84 Complete record for each day reported I ^nco 56.24% Prior status if a W.O. Drld 7" @ 9060' 8986' DPM PBTD, POOH w/perf rn #4 10.1+ NaC1/NaBr Accept rig @ 0600 hrs, 6/26/84. ND tree, NU &tst BOPE to 250/5000 psi. RIH'w/6-1/8" bit & tandem 7" csg scrprs to 8971' PBTD, cln hole & spot 10.8 ppg BridgeSal pill, POOH. Perf 8836'-8855', 8816'-8836', 8796'-8816' & 8762'-8784' @ 4 SPF, 90° phasing, POOH. 7" @ 9060' 8986' PBTD, Setting pkr 10.1+ NaC1/NaBr Perf 8700'-8730' & 8692'-8710' @ 12 SPF/120° phasing. Rn JB/gage ring to PBTD. PU Bkr FB-1 pkr, set @ 8743' WLM. RIH w/272 its, 3½" tbg, space out & lnd tbg w/SSSV @ 1931', PBR @ 8555', FHL Pkr @ 8568', FB-1Pkr @ 8781' Tbg Tail @ 8791' , GLM's @ 8675', 8607' & 8511', "D" Nipple @ 8789'. Drop ball for pkr setting. RECEIVED AUG 1 419B Alaska Oil & Gas Cons. Commission Anchorage The above 18 correct Signature ~. i Date I Title ARCO Oil and Gas-Company . Daily Well History-Final Report Inetru~iene: Prepare and ~..m~t~ t~_'~' o'1 the flmt Wednesday after allowable has been aulgned or well is Plugged, Abandoned, or Sold. "Fktal R~rt" ~hould be ' .~!;1~-:~~1%~ are lUll;ended for an indefinite or appreciable length ol time. On workovem when an official tell II not required upon compleflon,,~-'il'~:~ te~t data in blocke provided. The "F~II Re~e~l" form may be u~ed for reporting the entire operation if apace is lvailal~l.-.:_ ;,~ .-'-'- I . --~ i Accounting cost center code I DistriCt I County or Parish I State Alaska I; North Slope Borough I Alaska Field Lease or Unit Kuparuk River ADL #25570 Auth. or W.O. no. I Title AFE 901717 I Completion Operator IA'R'c°' w'I' IcostF°tal number °f wells (active °r inactive) °n thiSJcenter prior to plugging and .-: ARCO Alaska, Inc. . 56.24% labandonm~r,~, of lhis well Spudded or W.O. begun [Date IHour IPrior status if a W.O. Spudded 6/26/84 / 0600 Hrs. Well no. 2A-5 W/O r3ate and depth as of 8:00 a.m. 6/29/84 Complete record for each day reported 7" @ 9060' 8986' PBTD, RR Kuparuk crude in ann & tbg w/±20 bbl diesel cap in tbg Press tbg to 2500 psi, set pkr. Press ann to 2400 psi, press dropped to 2000 psi/8 min; ball had sheared out seat. Unlnd tbg, shear off PBR, relnd tbg, set BPV. ND BOPE, NU & tst tree to 250/5000 psi. Displ well w/30 bbls diesel, followed by crude. Set BPV, close SSSV. RR @ 1630 hrs, 6/28/84. Old TD New TD pR Depth - 9185' 8986' Released rig Date Kind of rig 1630 Hrs. 6/28/84 Rotary Classifications (oil, gas. etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Reservoir Producing Interval !Oil or gas Test time Production Oil on test Gas per day o . Pump size, SPM X length Choke aize T.P. C.P. Water % GOR Gravity Allowable El'fectlve date corrected The above is correct Signature Date ITItle 7/~/~, ::.':~: ': . . ~ ~ }"'"~ ~ : :: ....... ............ : ................. ............................................................ · ~-',."-~ ,% ,% ,** ~~-...~ ~, ~::: ::::::::.::. ::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: . : ~ "~'1'1 C' ';' " I "::'::: .... .... NUl¥ [ Er - .. _ :" . 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SL.IRVEVIIxI(3 P-I ' lI ~ l [ ~ ~ ANRHORAGE ALASKA i"~F:; :>'A--!5 ( .SEC :1. ,:ct. 'T' 1 1 N RSE ) COIdF:'U"I"A"I" I ON DA'I'E:' BC ~i"";~:i:; GYFi:OS(":()F'I C SI..IR~ KLIF'ARLII< .II INE :.'.'.",~ :l.'i?E:4 .... lOB NLIMBIEF~ AK--BCI-4C~O, · "l" R i...i ii;;: , :iii; L B-, S E A C ()i...I I:;~ '.iii: E C O i...I I::;~ '.iii: Ii.':: D O G-I_ E:' 13 'T' O T A I_ 1"~ ME:'A'i:. _ iI::;:E.['VE;R T' El; CAi VERT I C:AL.. INCL. ][ NA'I' I ("IN El I F;:E C"I" I (.)N'.iii;E}VE]::;~ I ']"Y I:;~El'.".:"l"¢-'-il',,ll_"iil_lL. ~-~1::~ CI]IClRI] INA [)EF'TH );)EJF:"i"H DEI="T'H I")E)3 M I I",1 DE (31::;,'1:i: i::i; :.:3 ~;il:ii[l":i/' ............... . ...... , ............... ..~w, .?,?~.~ ,..,. :¢ ? ........ .,.~. ............ ............ ,,.. ,, 4700 3489 63 '-"-'"'-'- :... . ..=,,:,,.., y, 63 · . . · 4800 3548.60 3418.60 49'Q0 :3607. 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(')A'.-;- '3~&~,.¢ =' 07M ~ ~ TOTAL DEF']~ DR ~ LLER 91 ~::F; /',?:':~'~:: ~} ~:::.~',:: 4::a44 ¢)'?':; 3945 ':~'-4~ ' ================================== ::::::::::: :': ::: '::.:: ::~: : ': ':'' ::"::::::'::: :~:'" : :: :::::~.: .: ':~::::::::?:::: ': .:...::::.::.::':.,.:.:,;:.,, .:,: :.-::.- , :. : : · : .;:.: :. ,',::;: :.x:::..: :,.:;:::::~:.:;::.:.:x::.:::,::.:::'::;::.::...:;..:+..:,:...:~>.,.~.~ .. ,: C:CJMF'UTA'I":I:~'"~N DATE dUIqF-:. 8, i984 ARCO Alaska, Inc. Our Boss Gyroscopic Survey · '-.:-~i-- JobNo';' AK-BO-40048 Well: ,DS 2A-5(SEC14 TllN R8E) ~'-? -K~-i Field North Slope, Alaska Survey Date: June 7, 1984 Operator: - Smith Scale: 1" = 1000' TRUE NORTH Surface Location 537 FSL 53 FEL J -4000.00 -3000.00 -2000. 00 -1000.00 9185 0.00 , -1000. O0 o ~ -2ooo. oo · --3000. O0 -4000.00 l_5000.00 HORI ZONTF L PROJECTION 1000 2000 3000 4000 5000 GO00 O0 O0 O0 O0 O0 O0 ARCO Alaska., Inc. Our Boss Gyroscopic Survey Job No. A/<-BO-40048 Well: DS 2A-5(SEC14 TllN R8E) Kuparuk Field North Slope, Alaska Survey Date: June 7, 1984 Operator: Smith Scale: 1" = 1000' 9185 6247.41 @ S 39° 9'W 1 1000. O0 2000. O0 3000. O0 4000. O0 5000. O0 6000. O0 7000. O0 VEfiTICfiL P R'O J E C 1-'I ON ' Suggested form to ]°'e inserted in each "Active" well-folder to d~.eck for ti~ly compliance with our regulations. Operator, ~ei i' Na~' Reports and Materials to be received by: Required Date Received Remarks · Ccmpletion Re~ort Yes Well History Yes _Samples Core Chips -' /~/~'~' Core Description .,~/~ ;z'"'-L~' Registered Survey Plat ~ Inclina~on S~ey ~/~..~ ~i~ ~.~ , Drill Stm Test Returns ,/~')/Q~-~?'- Digitiz~ ~ta VS,_¢ ARCO Alaska, Post Office'Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2A-4 3C-6 2A-5 2H-3 2A-6 2H-4 2A-7 Oliktok Pt. #2 CPF-2 Waste Water Disposal Thank you. Sincerely, A~~ Engineer JBK:jh L01 06/14/84 Enclosures RECEIVED JUN20] 4 Alaska 011 & Gas Cons. Commission Anohorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ~' STATE OF ALASKA ' ALAS~' _ AND GAS CONSERVATION ."MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS .... 1. Drilling well~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc' 84-67 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20030 4. Location of Well 9. Unit or Lease Name at surface Kuparuk River Unit 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ?_W_B 130' Pad 94'I ADL 25570 ALK 2668 537' FSL, 53' FEL, Sec. 14, TllN, R8E, UM 10. Well No. 2A-5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of May , 1~4 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks . Spudded well ~ 1500 hfs 5/6/84. Drld 12~" hole to 3229'. Ran, cmtd & tstd 9-5/8" csg. Drld 8½" hole to 9185'TD as of 5/13/84. Ran logs. Ran, cmtd & tstd 7" csg. Displ brine f/top 100' of well. Secured well & released rig @ 2000 hfs 5/16/84. Performed Arcticpk. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# J-55 H:F-ERW BTC csg w/shoe @ 3209', Class "G". Cmtd w/1000 sx Permafrost "E" & 250 sx 7" 26# J-55 HF-ERW BTC csg w/shoe @ 9060'. Cmtd w/350 sx Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/S?/FDC/CNL/CAL f/9100' to 3209'. RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data N/A JUN2 0 1984 Alaska 011 & Gas Cons, Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ///~" ~,/,'..,- ~' .~./"' //¢~ ~ ..... ' Area Drill±rig Engineer ~,~.~ SIGNED / / .r~///-,f.,~// .~ ~'~f,~,r~, TITLE ..... DATE NOTE--RI~/ort__ o~ t~/Corm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and .Gr~s Conse;K/a~on Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 ~// ~TT,T,/~R153 Submit in duplicate KUPARUK ENGINEERING Type of Tape ~a~e Tape ,qTA. g dgq%l l DISTRIBUTION .'-sta{e of AK OH LIS Sepia,~ Sign & return tb~attached.'._:, copy as receipt .~o~ data. ' ~ '- '.. />?..?/C;:'." ,; .. ,.~. . , ' .~-.. Return to: ARCO A~S~,.' INC. P.0. Box 100360 Anchorage, AK 99510 Please note- Blueline, Tape, Photocopy KUPARUK ENGINEERING Transmittal Date Run ~L DISTRIBUTION NSK Operation Blueline Dr il 1 ing Bluel ine Geology/L. J. BI/Se R&D Bluel ine D&M Blueline State BI/SE F.G. Baker Blueline D.B. Schafer Blueline G eology/Ken Film Sign & return the atta~c~IVED eopy~ as receipt of dat~.. ~ - ....... ~ Cons. Commission ~nchorage Return to: ARCO ALASKA, INC. ATTN: y'~uo,~ m. w'g-"rT/M ATO-1115B P.0. Box 100360 Anchorage, AK 99510 OHFinal MEMORANDUM TO: THRU: FROM: · State of Alaska ALASKA OIL AND GAS CONSERVATION COt,~ISSION c. v£1 ' ' ton Lonnie C. Smith Wii'~ Commissioner DoUg Amos ~ Petroleum Inspector DATE: May 17, 1984 FILE NO: D. 4I. 19 TELEPHONE NO: SUBJECT: Witness BOP Test on ARCO' s Kup 2A-5 Well, Sec. 14, TllN,RBE,UM, Permit No. 84-67 at Doyon Rig No. 9. Tuesday, May 8, 1984: After witnessing the BOP test at Parker Rig 176~ I'traveled '~,0 Doyon Rig #9 to witness the BOP test there. Wednesday, May 9, 1984: The BOP test commenced at 6:30 pm and was co'nci~ded' ~t 8:00 pm. There were no failures and I filled out an AOGCC' BOP test report which is attached. In s;,~ary, I witnessed the successful BOP test on ARCO's Kup 2A-5 Well. ~ At t aclnnent 02-001A(Rev. 10/79) O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Inspector Operator Representative Well K ~_?~ Location: Sec Drilling Contractor~~ ~v~ Rig # Permit # ~/~Casing Set @ ~~ ft. Representat iv~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE StaCk Annular Preventer Pipe Rams 'r ~- Blind Rams Choke Line Valves H.C.R. Valve ~" Kill Line Valves ~ Check Valve Test Results: Failures Test Pres sure - .. ACCUMULATOR SYSTEM Full Charge Pressure ~_~f~ ps ig Pressure After Closure ~ ~O psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: ~ N2 ~OO, ~9~ ~XPO/ Z?-OCg! psig O~ Controls: Master Q k~ Remote O~ Blinds switch cover Upper Kelly Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold Kelly and Floor Safety Valves I ~Test Pressure ~ I ~Test Pressure } ~ Test Pressure t ~Test Pressure ~ ~ Test Pressure No. Valves ~ ~ No. flanges ~1 Adjustable ~hokes Hydrauically'operated choke_. Test Time I hrs. ~O days and Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: min ~ sec. · min %( sec Distribut ion orig. - AO&GCC cc - Operator cc - Supervisor Inspector May 3, 1984 Mr. jeffrey Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 2A-'5 ARCO Alaska, Inc. Permit No. 84-67 Sur. Loc. 537'FSL, 53'FEL, Sec. ].4, TllN, RSE, Sec. 23, L~. Btmhole Loc. l128'FSL, !147'FWL, Sec. 23, TllN, RSE, UM. Dear Sir. Kewin : Enclosed is the approved application for permit to drill the above referenced well. if coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many riVers in Alaska and their drainage systems have been classified-as important for the spa~ing or migration of anadromous fish. Operations in these areas are subject: to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrativ~ Code, Chapter 70) and by the Fede~a!-Water Pollution ContrOl Act, as ~smended. Prior %o commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewin Kuparuk River Unit 2A-5 -2- May 3, 1984 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a dtverter system is required, Please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver~. t rul~z.~y~r s, ~ / 'C. ~. Chatterton sy ORBMR ~ THE CO~iSSION ~at~an of Alaska Oil and Gas Conservation Co~ission be Enclosure cc: Department of FiSh & Game, Habitat Section w/o encl. Department of Environmental ConserVation w/o encl. ARCO Alaska, Inc. Post Office B~.-- 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1984 Mr. C. V. Chatterton Commi ssi oner state of Alaska Alaska Oil & Gas Conservation commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2A-5 Dear Mr. Chatterton' Enclosed are: , o An applicati°n for permit to Drill Kuparuk 2A-5 al ong with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore . A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment s udding this well on May 11, 1984, your Since we estimate w~ll be appreciated. earl lest approval . . If you have any questions, please call me at 263-4970 Si/~ely' jBK/JG7/Lll:tW AttachmentS RECEIVED APR 2 7 Alaska 0il & Gas Cor~$. C0mmissfon Anchorage ARCO Ataska, inc. is a Subsidiary o! AtlanticRichlieldC°rnpany " STATE OF ALASKA ', ALASKA t~,L AND GAS CONSERVATION CO.,,~MISSION PERMIT TO DRILL la. Type of work. DRILL 20 AAC 25.O05 lb. Type of well EXPLORATORY [] SERVICE [] REDRILL [] DEEPEN [] DEVELOPMENT OIL E~X SINGLE ZONE I~X DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P, 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 537' FSL, 53' FEL, Sec,14, T11N, R8E, UN At top of proposed producing interval 1393' FSL, 1386' FWL, Sec. 23, TllN, R8E, UM At total depth 1128' FSL, 1147' FWL, Sec. 23, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 130', PAD 94' 6. Lease designation and serial no. ADL 25570 ALK 2668 9. Unit or lease name Kuparuk River Unit 10. Well number 2A-5 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposed depth (MD & TVD) 9124' MD, 6181' TVD feet 14. Distance to nearest property or lease line 1128 feet 17. Number of acres in lease 2560 15. Distance to nearest drilling or completed 2A-4well 280' ~ surface feet 18. Approximate spud date 05/11/84 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 53 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) 2756 3162 psig@ ROOF Surface psig@ 6060 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE , Hole I Casing i24" I 16" Weight 65.5# i12-1/4" 9-5/8" 36.0# 8-1/2" 7" 26.0# 22. Describe proposed pro§ram: CASING AND LINER Grade I Coup,ingl Length SETTING DEPTH MD TOP TVD 80' 36' I 36' I 3172' 35' 35' I I 33' I 33' MD BOTTOM TVD 116~ 116' 3207'I 2595' I 9124'1 6181' I QUANTITY OF CEMENT (include stage data) + 200 cf 690 sx Permafrost E & 250 sx Permafrost C 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9124' MD (6181' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2756 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Completion operations with the workover rig will be covered under a separate sundry notice. 2A-5 will be 280' away from 2A-4 at the surface. There are no closer we]lbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid (see attached sheet) 23. I hereby ~that the foregoing is true and correct to the best of my knowledge // //~/'/~,,,~ , TITLE Area Drilling Engineer The space ~ ~~iss.on use CONDITIONS OF APPROVAL DATE Samples required I-lYES ~JO Permit number APPROVED B Form 10401 Mud Icg required [] Y ES ~0 Approval date Directional Survey required I APl number I~xYES l-]NO I 50- / O 3- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE May 3, 1984 by order of the Commission Submit in triplicate Permit to Dril 1 2A-$ during any interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon completion of the job. ECEIVEb I } . } . ( . : ! i : I - ST ' ;' TV-B="f"-55t3-~--"HIr. ql, J-'x__.S.R D S ~-7--T_VD =--1; 57'- O_-l" s 6-4o'. E-F'.-=~;-,S ;~. · . , { . : 1 {. ; . i ' I ~ .... : ........... ,__ i: ~_, ........ x_ ......... .~ ....... ; ............ ~:___%.--'Z4_ _? ----'A-.4'-dc"..~~-,,, ........ -~ .... .~ ....... .T_._ i .... , .... ~_K-5~_TVD=..4420--~MD=621-8-DEP=3903---~..~--- --i-'.. ~---~."--,-~'"--/-~q£--,---!'; !' ~ i ' ; ...... ' .... ,F ' I I ' "~ ~ ~. ' . ; i ' L : I - ___L --' .... ~ ....... ; ...... C ................... -" ....... ..... ~ ~ .... ------q-~--:--:-h--~--~!---:~---~----h--'-~-t'-.:,~-1---- 'xC~_~/.-'-.~ ....... 'r'~,,Y,E.~'L-'!; : ...... ;-' . . ........ !..:_.:_._u_.~ ........ ~ i ........... h .... ~---i .... r~--'d-, .... ?----.1--'--~-~!' ...... "'L.' ""~'~L ...... r ,,-~,. : . . ' ,~ ; ; ..... 2~-- [ ..... ---- ~ _.__~_~ ....... _ i___.~__L.__~-- -~NN,C---~ _q'.~ .......... C0. ' .........- ....... ; ......... ': ...... ------"-----3 : | .... I t ~ - ~ ~ ~ ' ; '~ ,, ; . . . i :- .... '-' ! ., ;~,~.. ~, ', ;,' i, i.' ' ".~_,~ i -!, . ....... . : . i_--x- ..... ~-,-m-d'---~ ~ ' ' = .... ~ , ~ . ~ :~ ~-r ~-'-~'--. ---~"--~- "--~ - '} . ~ · ~*~,-;~---?-':---'-~ · ! - ~" · -" s -,--p ..... t .......... F-~ -- -~-~.o_----~-- ---"'~" ,'rap ,u~,P~--s~as ..... -...TV~5_~ o-'r.~=~e76-~EP--~.~ .. ...... - ~ ,- . · ~ .... ; .......... t ...... ~__ i '-----' .... ~ { .... i--TARI~ET CN'TR-,--TVD=5985-'THD=8800'DEP 5957 ....... i_..~,~ .... i .......... J ~ ' ' -' ' I' ' ~ --- ~ ......... !BASE- :KUP'--SNDS;--~-iTVD=6060- THD=8924. DEP=6056 ........ -~ ......................... t ..... ,. ! ........... -- i ........ ~ .......... 1 ..... ~. ; ',.TD--(LOGI~ING-"P'F)f .... TVD=618'If l'HD=9'I24'DEP=62'I5- + ....... [ ..........---- i. ........................................ -' ' .......... .... ; ........... - 4--: .Lu' .... ' . .............. ~.. : , ........,_--L-_--- ',, ~. ~ ;_;. :_ ;-i i ........... ', ...... : ....... i: ...... ;; i ......... .;-7 ..... !-,-; 7_ ;-j ....... !- 't ..... ~ ........ ; ~-'~ ......... ! ........... ¢ ..................... ~ZO00. · , - ..........t ......, ........ ; ....... ; ..... ! ......... ~ ....... ~ . . .- : -- -i---- i , i_ { : ~ · ~ .... ! .... '' ' ,'[ ' ........................ i ......... N ; ................. ..; :~ 1-: : DL-_z:~; ?'.----'---. 000;': ........ 2000:.:1%~_-.i'~': ~O001_.;-:.L ....... '4000 _. 5000 ..... 6000 .... FO0, ....... ; ........ . ..... .... " ................. -; ~ ~ ~ V ER-'T-I 0 AL=-S EC-I':'t ........ : ....... '~ ............ i .............. _ . ! '._.-, ~ ~ ..... i ......... ~ -- ~- ....... '"'.. : .................. i ........ ; - _.._t ............. i ...................... { ..... , ; .... ~ . , . · ............ .... ; ..... _ . I · ; i t ' I I f ARG1~-T'-~IE N'ft~R. ' i - ~ , , ,._, ........ .: ......... . ..... ~ ---. ....... i .... l ....... ~ ..... ~f---'~-~/--~ ...... --t ~ T¥I:)=5955'- ' ...... ~ ..... ~r i I ' .... :' ........ ', -- ....... .... .... " ......... !'-' ___._,-5000-' ' i ......... ......... rLO~C.~Ng~ ~T~i DEP-Sg57. '--i i .... .1TAR61ET32_Q'___F_$L..__lLOO^TI ON ~32_0,._ FWL' '; ....... ~ ........... -- - ~ .... ~$OOfH~9?~ SEC. Z3. ..... f llN R$£ - ............. ~ ...... :. ..... ~ ..... · -' ............... ~ ....... ' ......... ~ ........... ' ............. ; ........ i .... z:i- :--:----- i! .:-:-:--'~----'--.-i .-:-:-; ...... - - ~ _., . ~ ~ ~ ~ , WEST" i;3907 .............. ~ - · - i : ...... ~ ~ i I ~ p ~-' .. i _. ......... ~ ................. i T [ ~- i - ' .~ ~ . .............. ; .................. i ............. ! - ~ ~ i '' · ..... ~ ..... ! - ' - t ' ' - ~ ..... : ...... ~ ...... i _~6000 ~ : . ~ ....... e Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lO" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify 6hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Clo~e annular preventer in the event that gas or fluid flow to surface is detected. If necessary~ manually override and close ball valve to upwind diverter line. Do not shut in. well under an7 circumstances. 16" Conductor RF_CEIVED APR 2 71984 ,~,~ ~ 6a.s Cons. Commissior) Anchorage ANNULAR DIAGRAM ~1 13-5/8" 5000 PSi RSRRA BOP STACK PIP~ ~ 8 (' 1. 16" - 2000 psi Tanked s~ar:ing head Z. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/B" - 5000 psi spacer s~ool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams B. 13-5/8" - 5000 psi blind rams 9. 13-5/B" -.5000 psi annular BLIND 2 Alaska ECEIV£D APR 2 7 & Gas Cons. Commissio~ AnChorage ACCUMULATOR CAPACIT'f TEST L' 1. CHECX AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI RD4AINING PRESSURE. 13-5/B" BOP STACX TEST 1. FILL BOP STACK AND MAJiIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- EI). PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCX DOWN SCREWS IN HEAD: 3.CLOSE ANNULAR PRE"VENT'ER AND V/)J.,'V']~S UlPS~ OF CI-]O~S. DON.~T T]3ST AGAINST CLOSF. D CHOI<B SS 4. TEST ALL :DMPONENTS TO 2SO PSI AND HOL~'FOR tO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI ANO HOLD FOR tO a. ~'PR~SSUR]~ DOWNSTR~ OF CHOI<B ISOLATION V.A.L.I]~S. TO ZERO PSI TO TEST VALVES. TEST REJiAINING UNTESTED MANIFOLD .VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND 'ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP Si'F OF PIPE P, AJ~S AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR MINUTES BLEED TO ZERO PSi. 11. OPEN 80t'rOM S~T OF PIPE P, AMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P,~J~S AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN ORILLiNG POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14, TEST KELLY COCXS AND INSIDE BOP TO 3000 PSl WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPL[9'E BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. ARCO Alaska, Ir' Post Offic,. ,~ox 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 April 9, ]984 Hrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 300! Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2A-Pad Wells !-8 Dear Elaine' Enclosed is an as-built location plat for th'e subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG6/L85'tw Enclosure ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany ~ 0 ~o0 eO ? 0 6 0 5 o OF3 0 ~4 0~5 0 I O~ 14_~i 3 LOCATED IN SECTIONS . _ T liN',.RSE. UMIAT MERIDIAN. -. . - . _. . D.S 2-A 1:3, 14, 25,24~ DRit~''' SITE 2.A CONDUCTORS · BUILT LOCATIONS WELL-I X · 49B,B2Q996 227'FWL~ 717'FSL LA'[.= 70°18'083673' LONG = 150° OO' 40211" EL = 54.3, 0G=89.9 WELL-2 y= 5,950,078.4Z0 LAT=70°I8'O77789-' X: 498,6Z0.914 LO NB: 150° 00'4021-~'' · 227' FWd., 657' FSL EL= 94.4, OG :89.8 WELL-3 =5,9B0,018. 185 LAT: 70°18'071865' 498,620.912. LONG -'- 1500 O0'40ZI3'' 22T'F~fL, 597'FSL ' EL: 94.4,0G=89.6 WELL-4 Y:5,9 59,958.355 LAT = 70~ 18' 065~80'' X= 4~,520.9E, 9 LONG: 15OOO0'40ZII' ZZT'FWL, 537'FSL ' EL =94.5,0G: 90.4 WELL -5 Y =5,959, 958 261 LAT= 70016'06,5965. X= 498,340.910 LOJ~G=I$O° 00'483?$' 53'FEL , 537'FSL EL.: 94.0, OG= 69.5 WELL-6 Y = 5,960,018.341 LAT=70° 18'071874' X= 498~340.95B LONG:ISO°O0'48376'' 53'FEL, 597' FSL ' EL'-93.9~ OG =- $9.~- WELL-7 ¥=5~950,078. Z81 X' 498,3 4.0.9 06 53'FEL, 657'FSL LAT= 70°18'077769' LONG = 15 0°00'4 8;577' EL-' 93.8, 0(3 = 88.7' WELL-8 Y =5~960,13 8. 371 X = 498, 3 4.0.932. 53'FEL, 717 FSl.. LAT: 70°18'08~6 80" LONG= 150°00' 4 657 7" EL=95.7lOG = 87.8 DAVID FILUCCI ,-% OF Af.L' .~..~. .,,.,,.,., '~, ~,~.." A '... ,~, -...., ~../k..~ .... LICENSED 1-0 PRACTICE LAND SURVEYING IN THE STATE OF. CORRECT AS OF 5-21- 84 ~z~ ....... ~ ~]'~,~ DRILL SITE 2'A CONDUCTOR AS-BUILT LOCATIONS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend m Alter casing __ Repair well Change approved program _ Plugging Pull tubing __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 537' FSL, 53' FEL, SEC 14, T11N, R8E, UM At top of productive interval 1282' FSL, 1475' FWL, SEC 23, T11N, R8E, UM At effective depth 1102' FSL, 1410' FWL, SEC 23, T11N, R8E, UM At total depth 973' FSL, 1282' FWL, SEC 23, T11N, R8E, UM 12. Present well condition summary Operation Shutdown __ Re-enter suspended well __ Time extension_ Stimulate__ Variance ~ Perforate__ Other__ 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit feet 8. Well number ~A-05 9. Permit number I~4-67 10. APl number 50-103-20030 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Total Depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 918 5 true vertical 6235 measured 8979 true vertical 6096 Lenglh Size 104' 1 6' 3209' 9-5/8' 9060' 7' feet feet feet feet Plugs (measured) N3~E Junk (measured) NChE Cemented Measured depth 175 SX CS II 104' 1000 SX PERMAFROST E & 250 SX CLASS G 3209' 350 SX CLASS G & 250 SX PFC 9060' measured 8692'-8730', 8762'-8784', 8796'-8855' True vertical depth true vertical 5908-5930', 5950'-5965', 5973'-6103' Tubing (size, grade, and measured depth) 3-1/2' J-55 SET AT 8791' Packers and SSSV (type and measured depth) BAKER FHL PACKER @ 8530', BAKER FB-1 PACKER @ 8743', BAKER FVL SSSV @ 1893' 104' 2619' 6152' RECEIVED MAR 1 7 1994 A~aska Oil & Gas Cons. Commission .~ch0rage 13. Attachments Description summary of proposal Detailed operation program BOP sketch 14. Estimated date for commencing operation 3/20/94 oi~ X 16. If proposal was verbally approved Name of a. pprover DAVID JOHNSTON Date approved 3/15/94 Service 17. I hereby/'c~rtify th.at t~e foregoin, g is true and correct to the best of my knowledge. 15. Status of well classification as: Gas Suspended SR. PETROLEUM ENGINEER FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test _ Subsequent form require 10- II A P P ro9 ~,Z~ 6~¢ Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Commissioner Approved Copy SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 2A-05 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval for a variance to install a subsurface, ambient-type safety valve in Well 2A-05. This valve replaces the original subsurface safety valve which ,is n.__ot__. ~____o erable due to a control line failure. The replacement valve operates by remaining open until flowing well pressure ~ below a predetermined limit. Should such an event occur, the valve automatically closes thus preventing uncontrolled flow. This valve, refered to as a storm choke, does not require a hydraulic control line from the surface to the subsurface valve. Its fail-safe design as normally-closed provides the same level of protection as the original valve. RECEIVED MAR '1 7 1994 Oil & Gas Cons. Commission Anchorage CHECK LIST FOR NEW WELL PERMITS IT EM APPROVE DATE lo , 3. 4. 5. 6. 7. 8. 9· 10, 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. (21 thru" 24) 21. 22. 23. 24. 25. Company Lease & Well No. YES NO Is the permit fee attached ......................................... ~~_ Is well to be~located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party ...... "~:"~ ~ e·eeee·eeeeeeeeeeeeel~e.eee,"~*' ..... · · · ..~'~'" ! ~,,. Can. permit be approved before ten-day wait ....................... ~ REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ................................... Is enough cement used to circulat; on ~ductor a~d surface . . . - Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst , _ Is this well to be kicked off from an existing wellbore .............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ............................ Is a diverter system required ................................... Are necessary diagrams of diverter ~nd ~{ equipment attached . . Does BOPE have sufficient pressure rating - Test to ~~. psig .. Does the choke manifold comply w/API RP-53 (Feb. 78) .......... · Additional requirements ............................................. Additional Remarks: Geology: Engineering: LCS WVA...~ ~!l~~dJH 2"~T'~ JAL~_~m _...-~ rev: 12/08/83 6.CKLT INITIAL" GEO. UNIT' ON/OFF POOL CLASS STATUSI AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXl No 'special'effort has been made to chronologically organize this category of information, .o VP OlO.~O~. VERIFICATION LISTING PAGE * TAPE., HEADER ** ICRVt'C~ NAME : FO T'.t' ATE : R)~GIN ,,0000 ONF. 'IIA?IDN # EOF * F~LM WEADFR ** "I[,E NAM~ :~DTT ,001 E~VIC~ NA~E : E~S~ON # A?E : AXlPU. ~EN~TH : 1024 ire TYP., R~VTOH$ FTb~ : i'~ j~ ~A-sARCO AtAAKA TNC 'N' : KUPARUK 'ANG~ ~E OWN: 11N E:CT: 14 IO'UN: N,S~OP~ ;TA.T~ ~T~Y:t HSA ()NTT ?'¥PE CA?E SiZE CODE: 000 O0 065 000 OOg 016 004 065 000 000 008 065 00.0 000 002 065 000 000 004 065 000 000 002 065 00:0 0:00: 00:8 065 000 000 006 065 0:00 000 004 065 *********************************************************************************** $~HI,LI~BERGER ELL ~LD = KI!PARtI~ OtJN~¥ m NORTH ST,OPE BOROUGH T~T£ = ALA~K~ OB ~U~BER AT RCfl 69233 UN.#I. DA?E [,~GGEDI 15 HAY ~984 DP{ T 8~,.~ ~ 9.6~5" ~ ]206' - B{T STZ£ = ~.900" TO 9108' = 10 2 LB/G RM = 3 150 m 65,~ DF IBCOS~TY m 46:0 S RMF = 2:960 ~ 65,v DF = 9,5 RMC = 2 190 ~ 65__,_0 D~ : ~!)In LOSS = 4,4 C) RM AT B~T = ! 512 m ~4),.o ~F , SCHbI!~E~GE~ bOG~ ~NCbUD~ H~TH ?H~S MAGNETIC TAPEr * · DU~L INDI!C~InN SPHER~CALI.,Y F~CUSED hOG . COMPENSATE. ~EUTPON [,0~ (FDN~ 4 1 66 1 8 4 ?] 60 9 4 65 ,I~N 0 I 6~ 0 rT o o 0 4 OHMM ? 1 0 ~H~ 7 0 0 0 0 4 ~V ? ~ 0 00. 4 11 ° o G/C3 42 I 0 ~:~ 60 0 0 0 PU 42 2 0 0 CPS 42 34 92 0 0 4 API AP! 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HOB PHI p,, tH:OB 39~q902 6000,0000 -2~,7500 ,4453 5800.0000 87! 5800,0000 -2~.~500 .3008 32,6172 2~,7656 ...492 o :oooo 5100 0000 5~00,0000 ,~344 4t'0.645 2~, O0 4~','~I0 .412~ 5000,0000 ~FLU ~RI,.!O ~R ORHO ~FLU OR DR~O NCNb MCteL SFt.,U NCNb, -0 0034 2076:0000 801 2500 1216 1921,0000 2 9i02 104 37~0 0 0054 2039 0000 98.6875 2000,0000 2.5605 11§:,i875 ;059X 1944,0000 O, 049 1092,000:0 7 ,0000 ~.~402 NRA? ~CNb gR TL,D NRAT R'CNL, NR, Ai~ ~CNL NRAT FCNL' NRA! W'eNL, AT ILO 3.20q0 q48,2500 50] '3945 .7500 54~$000 ~ ),9395 478,~000 ,I'I 7 ~0 RNRA CAI, I RNRA CAb,1 RNRA C~L'I RNRA '~LM ~NRA ]:bM dALI 4,0000 3,1992 ,~,3008 3,8437 , 14 ~ 50'00 1], 3.6035 4goo.oooo -25,2556 ~,2676 4~,,2363 MCteL 4RO0.O000 0156 OR 4700,00~0 ~FI, U '7500 '2~,2402 32,37]0 £PT 4600 0000 SFLU PHOB .... -2~0~0~00 ORDR~O :P::.Hx 4 ~: ?500 ;¸PT 4,400,0000 ~FY,U .,32..~000 t';R 4~9 ' 0~0 13RHO 4]00, {4,~262 SFLU ~CNb 4200 ',' 3'6 3 ~13 DR~'O ~C~L {!HOB: 41oo 06 B 4000,i000 35~59~7 ~R DRHO NC~L 95,5000 0.0176 203~,0000 10~, ~0 O.Oj~8 199~,0000 2,5762 86.43?6 -0,0015 1~96.0000 ~.5371 ~1602 -O,OlgO 2022,0000 ,42]:8 0 193'6 9 213 0 2015 0'000 1574, 10A 1739 GR NRAT MRAT GR MRAT ~CNL ~R rCUL FCNI~ ~R NRR? tONI, TI~V rCNL NRIT ~RtT rC~L 95,5000 4~60 ,I:oooo 1,$19i 106,~S0 1.6094 450,?$00 96,0000 555,5000 3 5e~e 42~ '~i29 ,0000 {, 6691 4~:: o 1 409, 8~, ,, ot . CALl ~NRA CALl IbM CAbl RNRA CAbi RNR ,IbM I~NRA ClbI RN:RA YLM R NR A 10 7011 4785 i9 i~,8 6 4,i406 3,7520 3,42?'7 'l': o,, 4 l~ OIO.UO~ VERI~I~I?ION I,!$?ING Pi~ 9 ~PY 3900 0000 ~FLU gPT 3800,~000 ~, -39,7500 OR ~'OB I ~64! ~RH~ ~PT 3~00.0000 SFI,U p 46.7500 OR HOB 4~,i895 OReO EPT 3500,0000 SFI,,U p -46,5938 ~R PHI 41,~5~? ~C~b !',?T 3:~o~, oooo t~R~O 59 ~ 9609 HI 3'~ ?"5.00e"O ,0196 4 . 11.4219 77,5000 GR 0o1167 NRaT 1~60.0000 rCNI, 1.6055 lO?.O000 OR -0,~039 NRAT 195~.0000 9.8359 18~5 93'0122 NRAT 5.2539 8~,6250 ~R ,0083 MEAT 101t.0000 72,1879 ~R 0,'0205 ~RAT -0,00~9 HRAT ~RAT -0,3.:804 NRAT 1089;,0000 ~NL : NRMF I.,,DIT ,001 ~IC)~ # )ATE i 5.6.{98 II.,M 5,~!81 77,5000 CALl 11. 13 2,9609 RNRA 2, 66 68~.0000 813 0'00 CALl 101!27,3 RNRA 50:~, 500 10,~$00 IbM . RNRA 46 , i 4688 I M ' C~bI , 461 RNRA 501.7500 6,64~6 IbM 7~,1875 Clt, I ].%270 !RNRA ~37,0000 50? 19 5i CAbI P~IRA iR NRA: 8. 5,{547 :L2~.?422 , 2000,0000 VP O{~.,t~O~ VE~I~'ICATION [,.T.S?I~G PAGE 10 ********** EOF ********** * TAPF ?RRILE~ ** £RV~CE WA~E IFD~T RTE ~4/0~/~! ~XT T~PF NAME { OMM~NTS {[.,I~RARY TAPE RV?CF ~A~E {FD{T ONTTNtlATION # tO1 ********** EOF EOF
